FALSE2026Q1000108131612/31000007559412/31000109829612/31000092857612/31000007118012/31000009014412/31000160329112/31000193673712/3112http://fasb.org/srt/2025#AffiliatedEntityMemberhttp://fasb.org/srt/2025#AffiliatedEntityMember12http://fasb.org/srt/2025#AffiliatedEntityMemberhttp://fasb.org/srt/2025#AffiliatedEntityMember12xbrli:sharesiso4217:USDiso4217:USDxbrli:sharesbhe:operatingSegmentbhe:companybhe:statexbrli:purebhe:dayiso4217:GBPutr:acrebhe:structurebhe:class_memberbhe:complaintbhe:plaintiffbhe:casebhe:segmentbhe:Dthutr:MWhbhe:reportableSegmentutr:mi00010813162026-01-012026-03-310001081316bhe:PacificorpMember2026-01-012026-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMember2026-01-012026-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316bhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316bhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMember2026-01-012026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMember2026-01-012026-03-3100010813162026-04-300001081316bhe:PacificorpMember2026-04-300001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-04-300001081316bhe:NevadaPowerCompanyMember2026-04-300001081316bhe:SierraPacificPowerCompanyMember2026-04-300001081316bhe:EasternGasTransmissionAndStorageIncMember2026-04-3000010813162026-03-3100010813162025-12-310001081316bhe:ElectricityandnaturalgasMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMember2025-01-012025-03-310001081316bhe:ResidentialrealestatebrokerageandmortgagebusinessesMember2026-01-012026-03-310001081316bhe:ResidentialrealestatebrokerageandmortgagebusinessesMember2025-01-012025-03-3100010813162025-01-012025-03-310001081316us-gaap:PreferredStockMember2024-12-310001081316us-gaap:CommonStockMember2024-12-310001081316us-gaap:AdditionalPaidInCapitalMember2024-12-310001081316us-gaap:RetainedEarningsMember2024-12-310001081316us-gaap:AccumulatedOtherComprehensiveIncomeMember2024-12-310001081316us-gaap:NoncontrollingInterestMember2024-12-3100010813162024-12-310001081316us-gaap:RetainedEarningsMember2025-01-012025-03-310001081316us-gaap:NoncontrollingInterestMember2025-01-012025-03-310001081316us-gaap:AccumulatedOtherComprehensiveIncomeMember2025-01-012025-03-310001081316us-gaap:PreferredStockMember2025-01-012025-03-310001081316us-gaap:PreferredStockMember2025-03-310001081316us-gaap:CommonStockMember2025-03-310001081316us-gaap:AdditionalPaidInCapitalMember2025-03-310001081316us-gaap:RetainedEarningsMember2025-03-310001081316us-gaap:AccumulatedOtherComprehensiveIncomeMember2025-03-310001081316us-gaap:NoncontrollingInterestMember2025-03-3100010813162025-03-310001081316us-gaap:PreferredStockMember2025-12-310001081316us-gaap:CommonStockMember2025-12-310001081316us-gaap:AdditionalPaidInCapitalMember2025-12-310001081316us-gaap:RetainedEarningsMember2025-12-310001081316us-gaap:AccumulatedOtherComprehensiveIncomeMember2025-12-310001081316us-gaap:NoncontrollingInterestMember2025-12-310001081316us-gaap:RetainedEarningsMember2026-01-012026-03-310001081316us-gaap:NoncontrollingInterestMember2026-01-012026-03-310001081316us-gaap:AccumulatedOtherComprehensiveIncomeMember2026-01-012026-03-310001081316us-gaap:AdditionalPaidInCapitalMember2026-01-012026-03-310001081316us-gaap:PreferredStockMember2026-03-310001081316us-gaap:CommonStockMember2026-03-310001081316us-gaap:AdditionalPaidInCapitalMember2026-03-310001081316us-gaap:RetainedEarningsMember2026-03-310001081316us-gaap:AccumulatedOtherComprehensiveIncomeMember2026-03-310001081316us-gaap:NoncontrollingInterestMember2026-03-310001081316us-gaap:DisposalGroupHeldforsaleNotDiscontinuedOperationsMemberbhe:PacifiCorpAssetsAndLiabilitiesDisposalMemberbhe:PacificorpMember2026-02-150001081316us-gaap:DisposalGroupHeldforsaleNotDiscontinuedOperationsMemberbhe:PacifiCorpAssetsAndLiabilitiesDisposalMember2026-03-310001081316us-gaap:DisposalGroupHeldforsaleNotDiscontinuedOperationsMemberbhe:PacifiCorpAssetsAndLiabilitiesDisposalMemberbhe:UtilityGenerationDistributionAndTransmissionSystemMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MinimumMemberbhe:UtilityGenerationDistributionAndTransmissionSystemMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MaximumMemberbhe:UtilityGenerationDistributionAndTransmissionSystemMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:UtilityGenerationDistributionAndTransmissionSystemMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:UtilityGenerationDistributionAndTransmissionSystemMember2025-12-310001081316us-gaap:RegulatedOperationMembersrt:MinimumMemberus-gaap:PipelinesMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MaximumMemberus-gaap:PipelinesMember2026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:PipelinesMember2026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:PipelinesMember2025-12-310001081316us-gaap:RegulatedOperationMember2026-03-310001081316us-gaap:RegulatedOperationMember2025-12-310001081316us-gaap:UnregulatedOperationMembersrt:MinimumMemberbhe:IndependentPowerPlantsMember2026-03-310001081316us-gaap:UnregulatedOperationMembersrt:MaximumMemberbhe:IndependentPowerPlantsMember2026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:IndependentPowerPlantsMember2026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:IndependentPowerPlantsMember2025-12-310001081316us-gaap:UnregulatedOperationMemberbhe:LNGFacilityMember2026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:LNGFacilityMember2025-12-310001081316us-gaap:UnregulatedOperationMembersrt:MinimumMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2026-03-310001081316us-gaap:UnregulatedOperationMembersrt:MaximumMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2026-03-310001081316us-gaap:UnregulatedOperationMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2026-03-310001081316us-gaap:UnregulatedOperationMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2025-12-310001081316us-gaap:UnregulatedOperationMember2026-03-310001081316us-gaap:UnregulatedOperationMember2025-12-310001081316us-gaap:USTreasuryBillSecuritiesMember2026-03-310001081316us-gaap:USTreasuryBillSecuritiesMember2025-12-310001081316bhe:CompanyOwnedLifeInsuranceMember2026-03-310001081316bhe:CompanyOwnedLifeInsuranceMember2025-12-310001081316bhe:InvestmentsOtherMember2026-03-310001081316bhe:InvestmentsOtherMember2025-12-310001081316bhe:EquityMethodInvestmentstaxequityinvestmentsMember2026-03-310001081316bhe:EquityMethodInvestmentstaxequityinvestmentsMember2025-12-310001081316bhe:EquityMethodInvestmentsElectricTransmissionTexasLlcMember2026-03-310001081316bhe:EquityMethodInvestmentsElectricTransmissionTexasLlcMember2025-12-310001081316bhe:IroquoisGasTransmissionSystemL.P.Member2026-03-310001081316bhe:IroquoisGasTransmissionSystemL.P.Member2025-12-310001081316bhe:EquityMethodInvestmentsOtherMember2026-03-310001081316bhe:EquityMethodInvestmentsOtherMember2025-12-310001081316bhe:NuclearDecommissioningTrustFundsMember2026-03-310001081316bhe:NuclearDecommissioningTrustFundsMember2025-12-310001081316bhe:RestrictedCashAndInvestmentsOtherMember2026-03-310001081316bhe:RestrictedCashAndInvestmentsOtherMember2025-12-310001081316bhe:FirstMortgageBonds4.25Due2029Memberbhe:PacificorpMemberbhe:SubsidiarySeniorDebtMember2026-02-280001081316bhe:FirstMortgageBonds4.65Due2029Memberbhe:PacificorpMemberbhe:SubsidiarySeniorDebtMember2026-03-310001081316bhe:FirstMortgageBonds5.10Due2031Memberbhe:PacificorpMemberbhe:SubsidiarySeniorDebtMember2026-03-310001081316bhe:FirstMortgageBonds5.45Due2033Memberbhe:PacificorpMemberbhe:SubsidiarySeniorDebtMember2026-03-310001081316bhe:FirstMortgageBonds5.80Due2036Memberbhe:PacificorpMemberbhe:SubsidiarySeniorDebtMember2026-03-310001081316bhe:FixedToFixedResetRateJuniorSubordinatedNotes7.125Due2056Memberbhe:PacificorpMemberbhe:SubsidiaryJuniorSubordinatedDebtMember2026-02-280001081316bhe:FixedToFixedResetRateJuniorSubordinatedNotes6.375Due2056Memberbhe:SierraPacificPowerCompanyMemberbhe:SubsidiaryJuniorSubordinatedDebtMember2026-03-310001081316bhe:LetterOfCreditFacilityExpiring2028Memberbhe:PacificorpMemberus-gaap:LetterOfCreditMemberus-gaap:SubsequentEventMember2026-04-012026-04-300001081316bhe:LetterOfCreditFacilityExpiring2028Memberbhe:PacificorpMemberus-gaap:LetterOfCreditMemberus-gaap:SubsequentEventMember2026-04-300001081316bhe:SuretyFacilityMemberbhe:PacificorpMemberus-gaap:LineOfCreditMemberus-gaap:SubsequentEventMember2026-04-300001081316srt:ParentCompanyMember2026-03-310001081316srt:ParentCompanyMember2025-12-310001081316country:GB2026-01-012026-03-310001081316country:GB2025-01-012025-03-310001081316country:CA2026-01-012026-03-310001081316country:CA2025-01-012025-03-310001081316country:US2026-01-012026-03-310001081316country:US2025-01-012025-03-310001081316country:USus-gaap:PensionPlansDefinedBenefitMember2026-01-012026-03-310001081316country:USus-gaap:PensionPlansDefinedBenefitMember2025-01-012025-03-310001081316us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2026-01-012026-03-310001081316us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-01-012025-03-310001081316country:USus-gaap:PensionPlansDefinedBenefitMember2026-03-310001081316us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2026-03-310001081316country:GBus-gaap:PensionPlansDefinedBenefitMember2026-01-012026-03-310001081316country:GBus-gaap:PensionPlansDefinedBenefitMember2025-01-012025-03-310001081316country:GBus-gaap:PensionPlansDefinedBenefitMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:InterestRateContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316us-gaap:InterestRateContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:InterestRateContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316us-gaap:InterestRateContractMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:MortgagesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316us-gaap:MortgagesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:MortgagesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316us-gaap:MortgagesMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:InterestRateContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316us-gaap:InterestRateContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316us-gaap:InterestRateContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316us-gaap:InterestRateContractMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:MortgagesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316us-gaap:MortgagesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316us-gaap:MortgagesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316us-gaap:MortgagesMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:CommodityContractMember2025-12-310001081316us-gaap:InterestRateContractMember2025-12-310001081316us-gaap:CommodityContractMember2026-01-012026-03-310001081316us-gaap:InterestRateContractMember2026-01-012026-03-310001081316us-gaap:CommodityContractMember2026-03-310001081316us-gaap:InterestRateContractMember2026-03-310001081316us-gaap:CommodityContractMember2024-12-310001081316us-gaap:InterestRateContractMember2024-12-310001081316us-gaap:CommodityContractMember2025-01-012025-03-310001081316us-gaap:InterestRateContractMember2025-01-012025-03-310001081316us-gaap:CommodityContractMember2025-03-310001081316us-gaap:InterestRateContractMember2025-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMember2026-03-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Member2026-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMember2025-12-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Member2025-12-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:CapitalAdditionsMember2026-03-310001081316bhe:PacificorpMemberbhe:A2020WildfiresMember2020-09-012020-09-300001081316bhe:EconomicAndPropertyDamagesMemberus-gaap:PendingLitigationMemberbhe:JamesCaseMultnomahCountyCircuitCourtOregonInitialTrialMemberbhe:A2020WildfiresMemberbhe:PacificorpMember2021-11-012021-11-300001081316bhe:NoneconomicDamagesMemberus-gaap:PendingLitigationMemberbhe:JamesCaseMultnomahCountyCircuitCourtOregonInitialTrialMemberbhe:A2020WildfiresMemberbhe:PacificorpMember2021-11-012021-11-300001081316us-gaap:PendingLitigationMemberbhe:JamesCaseMultnomahCountyCircuitCourtOregonMassComplaintsMemberbhe:A2020WildfiresMemberbhe:PacificorpMember2024-04-012026-01-310001081316bhe:EconomicAndPropertyDamagesMemberus-gaap:PendingLitigationMemberbhe:JamesCaseMultnomahCountyCircuitCourtOregonMassComplaintsMemberbhe:A2020WildfiresMemberbhe:PacificorpMember2024-04-012026-01-310001081316bhe:NoneconomicAndPunitiveDamagesMemberus-gaap:PendingLitigationMemberbhe:JamesCaseMultnomahCountyCircuitCourtOregonMassComplaintsMemberbhe:A2020WildfiresMemberbhe:PacificorpMember2024-04-012026-01-310001081316bhe:JamesCaseMultnomahCountyCircuitCourtOregonInitialTrialMemberbhe:A2020WildfiresMemberbhe:PacificorpMember2023-06-012023-06-300001081316bhe:JamesCaseMultnomahCountyCircuitCourtOregonMemberbhe:A2020WildfiresMemberbhe:PacificorpMemberus-gaap:SubsequentEventMember2023-06-012026-04-300001081316us-gaap:SubsequentEventMemberbhe:DoubledEconomicDamagesMemberbhe:JamesCaseMultnomahCountyCircuitCourtOregonMemberbhe:A2020WildfiresMemberbhe:PacificorpMember2023-06-012026-04-300001081316us-gaap:SubsequentEventMemberbhe:NoneconomicDamagesMemberbhe:JamesCaseMultnomahCountyCircuitCourtOregonMemberbhe:A2020WildfiresMemberbhe:PacificorpMember2023-06-012026-04-300001081316us-gaap:SubsequentEventMemberbhe:PunitiveDamagesMemberbhe:JamesCaseMultnomahCountyCircuitCourtOregonMemberbhe:A2020WildfiresMemberbhe:PacificorpMember2023-06-012026-04-300001081316bhe:JamesCaseMultnomahCountyCircuitCourtOregonMemberbhe:A2020WildfiresMemberbhe:PacificorpMemberus-gaap:SubsequentEventMember2026-05-010001081316us-gaap:SubsequentEventMemberus-gaap:JudicialRulingMemberbhe:JamesCaseMultnomahCountyCircuitCourtOregonMemberbhe:A2020WildfiresMemberbhe:PacificorpMember2023-06-012026-04-300001081316bhe:PacificorpMemberbhe:WildfiresMember2026-03-310001081316bhe:PacificorpMemberbhe:WildfiresMember2022-01-012026-03-310001081316bhe:WildfiresMemberbhe:PacificorpMemberus-gaap:SubsequentEventMember2026-04-012026-04-300001081316bhe:PacificorpMemberbhe:WildfiresMember2025-12-310001081316bhe:PacificorpMemberbhe:WildfiresMember2024-12-310001081316bhe:PacificorpMemberbhe:WildfiresMember2026-01-012026-03-310001081316bhe:PacificorpMemberbhe:WildfiresMember2025-01-012025-03-310001081316bhe:PacificorpMemberbhe:WildfiresMember2025-03-310001081316bhe:PacificorpMember2026-03-310001081316bhe:PacificorpMember2025-12-310001081316bhe:TexasStateLawAntitrustClaimsMemberbhe:AntitrustMemberbhe:HomeservicesMember2026-01-012026-03-310001081316bhe:BurnettVsHomeServicesOfAmericaIncMemberbhe:AntitrustMemberbhe:HomeservicesMember2023-10-162023-10-160001081316bhe:BurnettVsHomeServicesOfAmericaIncMemberbhe:AntitrustMemberbhe:HomeservicesMember2024-04-012024-04-300001081316bhe:BurnettVsHomeServicesOfAmericaIncMemberbhe:AntitrustMemberbhe:HomeservicesMember2024-09-012024-09-300001081316bhe:BurnettVsHomeServicesOfAmericaIncMemberbhe:AntitrustMemberbhe:HomeservicesMember2025-02-012025-02-280001081316bhe:BurnettVsHomeServicesOfAmericaIncMemberbhe:AntitrustMemberbhe:HomeservicesMember2026-02-012026-02-280001081316bhe:BurnettVsHomeServicesOfAmericaIncMemberbhe:AntitrustMemberbhe:HomeservicesMember2024-01-012024-03-310001081316bhe:BurnettVsHomeServicesOfAmericaIncMemberbhe:AntitrustMemberbhe:HomeservicesMember2026-03-310001081316bhe:BurnettVsHomeServicesOfAmericaIncMemberbhe:AntitrustMemberbhe:HomeservicesMember2025-12-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMember2026-01-012026-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2026-01-012026-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2026-01-012026-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2026-01-012026-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2026-01-012026-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2026-01-012026-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2026-01-012026-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMember2026-01-012026-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2026-01-012026-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2026-01-012026-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2026-01-012026-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2026-01-012026-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2026-01-012026-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2026-01-012026-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:MidamericanFundingMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:NVEnergyInc.Member2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:BHEPipelineGroupMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:BHETransmissionMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:BHERenewablesMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:MidamericanFundingMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:NVEnergyInc.Member2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:BHEPipelineGroupMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:BHETransmissionMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:BHERenewablesMember2026-01-012026-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:BerkshireHathawayEnergyAndOtherMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMember2025-01-012025-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2025-01-012025-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2025-01-012025-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2025-01-012025-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2025-01-012025-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2025-01-012025-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2025-01-012025-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2025-01-012025-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMember2025-01-012025-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2025-01-012025-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2025-01-012025-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2025-01-012025-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2025-01-012025-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2025-01-012025-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2025-01-012025-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2025-01-012025-03-310001081316bhe:RegulatedinterstatepipelineMemberus-gaap:RegulatedOperationMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:MidamericanFundingMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:NVEnergyInc.Member2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:NorthernPowergridHoldingsMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:BHEPipelineGroupMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:BHETransmissionMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:BHERenewablesMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:RegulatedOperationMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:MidamericanFundingMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:NVEnergyInc.Member2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:NorthernPowergridHoldingsMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:BHEPipelineGroupMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:BHETransmissionMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:BHERenewablesMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMemberbhe:BerkshireHathawayEnergyAndOtherMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberus-gaap:UnregulatedOperationMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:MidamericanFundingMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:NVEnergyInc.Member2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:NorthernPowergridHoldingsMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:BHEPipelineGroupMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:BHETransmissionMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:BHERenewablesMember2025-01-012025-03-310001081316bhe:ElectricityandnaturalgasMemberbhe:BerkshireHathawayEnergyAndOtherMember2025-01-012025-03-310001081316bhe:ResidentialrealestatebrokerageMemberbhe:HomeservicesMember2026-01-012026-03-310001081316bhe:ResidentialrealestatebrokerageMemberbhe:HomeservicesMember2025-01-012025-03-310001081316bhe:RealestatefranchiseMemberbhe:HomeservicesMember2026-01-012026-03-310001081316bhe:RealestatefranchiseMemberbhe:HomeservicesMember2025-01-012025-03-310001081316bhe:ResidentialrealestatebrokerageandmortgagebusinessesMemberbhe:HomeservicesMember2026-01-012026-03-310001081316bhe:ResidentialrealestatebrokerageandmortgagebusinessesMemberbhe:HomeservicesMember2025-01-012025-03-310001081316bhe:BHEPipelineGroupMember2026-04-012026-03-310001081316bhe:BHEPipelineGroupMember2027-04-012026-03-310001081316bhe:BHEPipelineGroupMember2026-03-310001081316us-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2024-12-310001081316us-gaap:AccumulatedForeignCurrencyAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2024-12-310001081316us-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2024-12-310001081316us-gaap:AociAttributableToNoncontrollingInterestMember2024-12-310001081316us-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2025-01-012025-03-310001081316us-gaap:AccumulatedForeignCurrencyAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2025-01-012025-03-310001081316us-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2025-01-012025-03-310001081316us-gaap:AociAttributableToNoncontrollingInterestMember2025-01-012025-03-310001081316us-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2025-03-310001081316us-gaap:AccumulatedForeignCurrencyAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2025-03-310001081316us-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2025-03-310001081316us-gaap:AociAttributableToNoncontrollingInterestMember2025-03-310001081316us-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2025-12-310001081316us-gaap:AccumulatedForeignCurrencyAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2025-12-310001081316us-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2025-12-310001081316us-gaap:AociAttributableToNoncontrollingInterestMember2025-12-310001081316us-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2026-01-012026-03-310001081316us-gaap:AccumulatedForeignCurrencyAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2026-01-012026-03-310001081316us-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2026-01-012026-03-310001081316us-gaap:AociAttributableToNoncontrollingInterestMember2026-01-012026-03-310001081316us-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2026-03-310001081316us-gaap:AccumulatedForeignCurrencyAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2026-03-310001081316us-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2026-03-310001081316us-gaap:AociAttributableToNoncontrollingInterestMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:PacificorpMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanFundingMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:NVEnergyInc.Member2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:BHEPipelineGroupMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:BHETransmissionMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:BHERenewablesMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:HomeservicesMember2026-01-012026-03-310001081316bhe:CorporateAndEliminationsMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:PacificorpMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanFundingMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:NVEnergyInc.Member2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:NorthernPowergridHoldingsMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:BHEPipelineGroupMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:BHETransmissionMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:BHERenewablesMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:HomeservicesMember2025-01-012025-03-310001081316bhe:CorporateAndEliminationsMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:PacificorpMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:PacificorpMember2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanFundingMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanFundingMember2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:NVEnergyInc.Member2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:NVEnergyInc.Member2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:NorthernPowergridHoldingsMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:NorthernPowergridHoldingsMember2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:BHEPipelineGroupMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:BHEPipelineGroupMember2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:BHETransmissionMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:BHETransmissionMember2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:BHERenewablesMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:BHERenewablesMember2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:HomeservicesMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:HomeservicesMember2025-12-310001081316bhe:CorporateAndEliminationsMember2026-03-310001081316bhe:CorporateAndEliminationsMember2025-12-310001081316bhe:PacificorpMember2025-12-310001081316bhe:MidamericanFundingMember2025-12-310001081316bhe:NVEnergyInc.Member2025-12-310001081316bhe:NorthernPowergridHoldingsMember2025-12-310001081316bhe:BHEPipelineGroupMember2025-12-310001081316bhe:BHETransmissionMember2025-12-310001081316bhe:BHERenewablesMember2025-12-310001081316bhe:HomeservicesMember2025-12-310001081316bhe:PacificorpMember2026-01-012026-03-310001081316bhe:MidamericanFundingMember2026-01-012026-03-310001081316bhe:NVEnergyInc.Member2026-01-012026-03-310001081316bhe:NorthernPowergridHoldingsMember2026-01-012026-03-310001081316bhe:BHEPipelineGroupMember2026-01-012026-03-310001081316bhe:BHETransmissionMember2026-01-012026-03-310001081316bhe:BHERenewablesMember2026-01-012026-03-310001081316bhe:HomeservicesMember2026-01-012026-03-310001081316bhe:PacificorpMember2026-03-310001081316bhe:MidamericanFundingMember2026-03-310001081316bhe:NVEnergyInc.Member2026-03-310001081316bhe:NorthernPowergridHoldingsMember2026-03-310001081316bhe:BHETransmissionMember2026-03-310001081316bhe:BHERenewablesMember2026-03-310001081316bhe:HomeservicesMember2026-03-310001081316bhe:PacificorpMember2025-01-012025-03-310001081316bhe:PacificorpMemberus-gaap:PreferredStockMember2024-12-310001081316bhe:PacificorpMemberus-gaap:CommonStockMember2024-12-310001081316bhe:PacificorpMemberus-gaap:AdditionalPaidInCapitalMember2024-12-310001081316bhe:PacificorpMemberus-gaap:RetainedEarningsMember2024-12-310001081316bhe:PacificorpMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2024-12-310001081316bhe:PacificorpMember2024-12-310001081316bhe:PacificorpMemberus-gaap:RetainedEarningsMember2025-01-012025-03-310001081316bhe:PacificorpMemberus-gaap:PreferredStockMember2025-01-012025-03-310001081316bhe:PacificorpMemberus-gaap:PreferredStockMember2025-03-310001081316bhe:PacificorpMemberus-gaap:CommonStockMember2025-03-310001081316bhe:PacificorpMemberus-gaap:AdditionalPaidInCapitalMember2025-03-310001081316bhe:PacificorpMemberus-gaap:RetainedEarningsMember2025-03-310001081316bhe:PacificorpMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-03-310001081316bhe:PacificorpMember2025-03-310001081316bhe:PacificorpMemberus-gaap:PreferredStockMember2025-12-310001081316bhe:PacificorpMemberus-gaap:CommonStockMember2025-12-310001081316bhe:PacificorpMemberus-gaap:AdditionalPaidInCapitalMember2025-12-310001081316bhe:PacificorpMemberus-gaap:RetainedEarningsMember2025-12-310001081316bhe:PacificorpMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-12-310001081316bhe:PacificorpMemberus-gaap:RetainedEarningsMember2026-01-012026-03-310001081316bhe:PacificorpMemberus-gaap:PreferredStockMember2026-03-310001081316bhe:PacificorpMemberus-gaap:CommonStockMember2026-03-310001081316bhe:PacificorpMemberus-gaap:AdditionalPaidInCapitalMember2026-03-310001081316bhe:PacificorpMemberus-gaap:RetainedEarningsMember2026-03-310001081316bhe:PacificorpMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2026-03-310001081316us-gaap:DisposalGroupHeldforsaleNotDiscontinuedOperationsMemberbhe:PacifiCorpAssetsAndLiabilitiesDisposalMemberbhe:PacificorpMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MinimumMemberbhe:PacificorpMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMembersrt:MaximumMemberbhe:PacificorpMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-12-310001081316us-gaap:UnregulatedOperationMembersrt:MinimumMemberbhe:PacificorpMember2026-01-012026-03-310001081316us-gaap:UnregulatedOperationMembersrt:MaximumMemberbhe:PacificorpMember2026-01-012026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:PacificorpMember2026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:PacificorpMember2025-12-310001081316bhe:PacificorpMember2025-01-012025-12-310001081316bhe:PacificorpMemberus-gaap:RelatedPartyMember2026-03-310001081316us-gaap:DomesticCountryMemberus-gaap:RelatedPartyMemberbhe:PacificorpMember2025-12-310001081316us-gaap:StateAndLocalJurisdictionMemberus-gaap:RelatedPartyMemberbhe:PacificorpMember2025-12-310001081316country:USus-gaap:PensionPlansDefinedBenefitMemberbhe:PacificorpMember2026-01-012026-03-310001081316country:USus-gaap:PensionPlansDefinedBenefitMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:PacificorpMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2026-01-012026-03-310001081316bhe:PacificorpMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-01-012025-03-310001081316country:USus-gaap:PensionPlansDefinedBenefitMemberbhe:PacificorpMember2026-03-310001081316bhe:PacificorpMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherCurrentAssetsMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentAssetsMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherCurrentLiabilitiesMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentLiabilitiesMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherCurrentAssetsMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentAssetsMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherCurrentLiabilitiesMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentLiabilitiesMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherCurrentAssetsMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentAssetsMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:OtherCurrentLiabilitiesMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentLiabilitiesMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:OtherCurrentAssetsMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentAssetsMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:OtherCurrentLiabilitiesMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentLiabilitiesMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2024-12-310001081316us-gaap:CommodityContractMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2026-01-012026-03-310001081316us-gaap:CommodityContractMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2025-01-012025-03-310001081316us-gaap:CommodityContractMemberus-gaap:NondesignatedMemberbhe:PacificorpMember2025-03-310001081316us-gaap:CommodityContractMemberbhe:NaturalGasPurchasesMemberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberbhe:NaturalGasPurchasesMemberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:PacificorpMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:PacificorpMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:PacificorpMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:PacificorpMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:PacificorpMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:PacificorpMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:PacificorpMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:PacificorpMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:PacificorpMember2026-03-310001081316bhe:PacificorpMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:PacificorpMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:PacificorpMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:PacificorpMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:PacificorpMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:PacificorpMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:PacificorpMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:PacificorpMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:PacificorpMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:PacificorpMember2025-12-310001081316bhe:PacificorpMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:PacificorpMember2026-03-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:PacificorpMember2026-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:PacificorpMember2025-12-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:PacificorpMember2025-12-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:ResidentialMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:ResidentialMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:CommercialMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:CommercialMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:IndustrialMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:IndustrialMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:OtherMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:OtherMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:RegulatedtransmissionanddistributionMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:PacificorpMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:PacificorpMember2025-01-012025-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:ElectricityUsRegulatedMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:ElectricityUsRegulatedMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:RegulatednaturalgasandotherMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316bhe:RegulatednaturalgasandotherMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:CommonStockMember2024-12-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:AdditionalPaidInCapitalMember2024-12-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:RetainedEarningsMember2024-12-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMember2024-12-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:RetainedEarningsMember2025-01-012025-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:CommonStockMember2025-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:AdditionalPaidInCapitalMember2025-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:RetainedEarningsMember2025-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:CommonStockMember2025-12-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:AdditionalPaidInCapitalMember2025-12-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:RetainedEarningsMember2025-12-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:RetainedEarningsMember2026-01-012026-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:CommonStockMember2026-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:AdditionalPaidInCapitalMember2026-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:RetainedEarningsMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MinimumMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMembersrt:MaximumMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:RegulatedOperationMemberbhe:ElectricOperationsMembersrt:MinimumMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:ElectricOperationsMembersrt:MaximumMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:ElectricOperationsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:ElectricOperationsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:RegulatedOperationMemberus-gaap:NaturalGasProcessingPlantMembersrt:MinimumMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:NaturalGasProcessingPlantMembersrt:MaximumMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:NaturalGasProcessingPlantMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:NaturalGasProcessingPlantMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:UnregulatedOperationMembersrt:MinimumMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:UnregulatedOperationMembersrt:MaximumMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:RevenueSharingArrangementAnticipatedEquityReturnsExceedingThresholdMember2026-01-012026-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:RevenueSharingArrangementAnticipatedEquityReturnsExceedingThresholdMember2025-01-012025-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:RelatedPartyMember2026-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:RelatedPartyMember2025-12-310001081316country:USus-gaap:PensionPlansDefinedBenefitMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316country:USus-gaap:PensionPlansDefinedBenefitMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2026-01-012026-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-01-012025-03-310001081316country:USus-gaap:PensionPlansDefinedBenefitMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:USTreasurySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:DomesticCorporateDebtSecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:MunicipalBondsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:DomesticEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:ForeignEquitySecuritiesMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:CommodityMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:CommodityMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2024-12-310001081316us-gaap:CommodityMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:CommodityMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316us-gaap:CommodityMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:CommodityMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:ResidentialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:ResidentialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:ResidentialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:CommercialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:CommercialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:CommercialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:IndustrialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:IndustrialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:IndustrialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:NaturalgasdistributiontransportationonlyservicesMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:NaturalgasdistributiontransportationonlyservicesMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:OtherMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:OtherMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:OtherMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316bhe:ElectricityTransmissionMemberus-gaap:RegulatedOperationMemberbhe:MultivaluetransmissionprojectsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:ElectricityTransmissionMemberus-gaap:RegulatedOperationMemberbhe:MultivaluetransmissionprojectsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:UnregulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:CorporateAndOtherMember2026-01-012026-03-310001081316bhe:OtherCustomerRevenueMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:CorporateAndOtherMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:ResidentialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:ResidentialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:ResidentialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:CommercialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:CommercialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:CommercialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:IndustrialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:IndustrialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:IndustrialMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:NaturalgasdistributiontransportationonlyservicesMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:NaturalgasdistributiontransportationonlyservicesMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:OtherMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:OtherMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:OtherMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedretailMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedwholesaleMemberus-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:ElectricityTransmissionMemberus-gaap:RegulatedOperationMemberbhe:MultivaluetransmissionprojectsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:ElectricityTransmissionMemberus-gaap:RegulatedOperationMemberbhe:MultivaluetransmissionprojectsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberus-gaap:UnregulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:CorporateAndOtherMember2025-01-012025-03-310001081316bhe:OtherCustomerRevenueMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:UnregulatedOperationMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberus-gaap:CorporateAndOtherMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:CorporateNonSegmentMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:CorporateNonSegmentMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-12-310001081316us-gaap:CorporateNonSegmentMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2026-03-310001081316us-gaap:CorporateNonSegmentMemberbhe:MidamericanEnergyCompanyAndSubsidiariesMember2025-12-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMember2026-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMember2025-12-310001081316us-gaap:ElectricityUsRegulatedMemberbhe:MidAmericanFundingLLCAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:ElectricityUsRegulatedMemberbhe:MidAmericanFundingLLCAndSubsidiariesMember2025-01-012025-03-310001081316bhe:RegulatednaturalgasandotherMemberbhe:MidAmericanFundingLLCAndSubsidiariesMember2026-01-012026-03-310001081316bhe:RegulatednaturalgasandotherMemberbhe:MidAmericanFundingLLCAndSubsidiariesMember2025-01-012025-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMember2025-01-012025-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:AdditionalPaidInCapitalMember2024-12-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:RetainedEarningsMember2024-12-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMember2024-12-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:RetainedEarningsMember2025-01-012025-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:AdditionalPaidInCapitalMember2025-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:RetainedEarningsMember2025-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMember2025-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:AdditionalPaidInCapitalMember2025-12-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:RetainedEarningsMember2025-12-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:RetainedEarningsMember2026-01-012026-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:AdditionalPaidInCapitalMember2026-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:RetainedEarningsMember2026-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2026-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2025-12-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:RelatedPartyMember2026-03-310001081316bhe:MidAmericanFundingLLCAndSubsidiariesMemberus-gaap:RelatedPartyMember2025-12-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:MidAmericanFundingLLCAndSubsidiariesMember2026-03-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:MidAmericanFundingLLCAndSubsidiariesMember2026-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:MidAmericanFundingLLCAndSubsidiariesMember2025-12-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:MidAmericanFundingLLCAndSubsidiariesMember2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:MidAmericanFundingLLCAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidAmericanFundingLLCAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:CorporateNonSegmentMemberbhe:MidAmericanFundingLLCAndSubsidiariesMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidAmericanFundingLLCAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidAmericanFundingLLCAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:CorporateNonSegmentMemberbhe:MidAmericanFundingLLCAndSubsidiariesMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidAmericanFundingLLCAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidAmericanFundingLLCAndSubsidiariesMemberbhe:ElectricityRegulatedSegmentMember2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:MidAmericanFundingLLCAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:MidAmericanFundingLLCAndSubsidiariesMemberbhe:NaturalGasRegulatedSegmentMember2025-12-310001081316us-gaap:CorporateNonSegmentMemberbhe:MidAmericanFundingLLCAndSubsidiariesMember2026-03-310001081316us-gaap:CorporateNonSegmentMemberbhe:MidAmericanFundingLLCAndSubsidiariesMember2025-12-310001081316bhe:NevadaPowerCompanyMember2026-03-310001081316bhe:NevadaPowerCompanyMember2025-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:NonrelatedPartyMember2026-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:NonrelatedPartyMember2025-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:RelatedPartyMember2026-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:RelatedPartyMember2025-12-310001081316bhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:CommonStockMember2024-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2024-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:RetainedEarningsMember2024-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2024-12-310001081316bhe:NevadaPowerCompanyMember2024-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:RetainedEarningsMember2025-01-012025-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:CommonStockMember2025-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2025-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:RetainedEarningsMember2025-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-03-310001081316bhe:NevadaPowerCompanyMember2025-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:CommonStockMember2025-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2025-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:RetainedEarningsMember2025-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:RetainedEarningsMember2026-01-012026-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2026-01-012026-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:CommonStockMember2026-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2026-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:RetainedEarningsMember2026-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MinimumMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMembersrt:MaximumMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:UnregulatedOperationMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:NevadaPowerCompanyMember2025-12-310001081316bhe:NPCPollutionControlRefundingRevenueBonds3.750Series2017Due2036Memberbhe:NevadaPowerCompanyMemberbhe:SubsidiaryDebtMember2026-03-012026-03-310001081316bhe:NPCPollutionControlRefundingRevenueBonds4.125Series2017ADue2032Memberbhe:NevadaPowerCompanyMemberbhe:SubsidiaryDebtMember2026-03-012026-03-310001081316bhe:NPCPollutionControlRefundingRevenueBonds3.750Series2017BDue2039Memberbhe:NevadaPowerCompanyMemberbhe:SubsidiaryDebtMember2026-03-012026-03-310001081316us-gaap:OtherNoncurrentAssetsMemberbhe:NVEnergyInc.Memberus-gaap:PensionPlansDefinedBenefitMembercountry:USbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:OtherNoncurrentAssetsMemberbhe:NVEnergyInc.Memberus-gaap:PensionPlansDefinedBenefitMembercountry:USbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:OtherCurrentLiabilitiesMemberbhe:NVEnergyInc.Memberus-gaap:OtherPensionPlansDefinedBenefitMembercountry:USbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:OtherCurrentLiabilitiesMemberbhe:NVEnergyInc.Memberus-gaap:OtherPensionPlansDefinedBenefitMembercountry:USbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:OtherNoncurrentLiabilitiesMemberbhe:NVEnergyInc.Memberus-gaap:OtherPensionPlansDefinedBenefitMembercountry:USbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:OtherNoncurrentLiabilitiesMemberbhe:NVEnergyInc.Memberus-gaap:OtherPensionPlansDefinedBenefitMembercountry:USbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:OtherNoncurrentAssetsMemberbhe:NVEnergyInc.Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembercountry:USbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:OtherNoncurrentAssetsMemberbhe:NVEnergyInc.Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembercountry:USbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberbhe:DerivativeLiabilityCurrentMemberus-gaap:NondesignatedMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentLiabilitiesMemberus-gaap:NondesignatedMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:NondesignatedMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberbhe:DerivativeLiabilityCurrentMemberus-gaap:NondesignatedMemberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentLiabilitiesMemberus-gaap:NondesignatedMemberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:NondesignatedMemberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316us-gaap:CommodityContractMemberbhe:NevadaPowerCompanyMember2025-01-012025-12-310001081316us-gaap:CommodityContractMemberbhe:NaturalGasPurchasesMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberbhe:NaturalGasPurchasesMemberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:NevadaPowerCompanyMember2026-03-310001081316bhe:NevadaPowerCompanyMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:NevadaPowerCompanyMember2025-12-310001081316bhe:NevadaPowerCompanyMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:CommodityMemberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:CommodityMemberbhe:NevadaPowerCompanyMember2024-12-310001081316us-gaap:CommodityMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316us-gaap:CommodityMemberbhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316us-gaap:CommodityMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:CommodityMemberbhe:NevadaPowerCompanyMember2025-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:NevadaPowerCompanyMember2026-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:NevadaPowerCompanyMember2025-12-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:NevadaPowerCompanyMember2025-12-310001081316bhe:NevadaPowerCompanyMemberbhe:CustomerRefundMember2026-03-310001081316bhe:NevadaPowerCompanyMemberbhe:CustomerRefundMember2025-12-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:ResidentialMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:ResidentialMemberbhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:CommercialMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:CommercialMemberbhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:IndustrialMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:IndustrialMemberbhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:OtherMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:OtherMemberbhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:DistributiononlyserviceMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:DistributiononlyserviceMemberbhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedwholesaletransmissionandotherMemberus-gaap:RegulatedOperationMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedwholesaletransmissionandotherMemberus-gaap:RegulatedOperationMemberbhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:NevadaPowerCompanyMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:NevadaPowerCompanyMember2025-01-012025-03-310001081316bhe:SierraPacificPowerCompanyMember2026-03-310001081316bhe:SierraPacificPowerCompanyMember2025-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:NonrelatedPartyMember2026-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:NonrelatedPartyMember2025-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:RelatedPartyMember2026-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:RelatedPartyMember2025-12-310001081316us-gaap:ElectricityUsRegulatedMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:ElectricityUsRegulatedMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316us-gaap:NaturalGasUsRegulatedMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:NaturalGasUsRegulatedMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316bhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:CommonStockMember2024-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2024-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:RetainedEarningsMember2024-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2024-12-310001081316bhe:SierraPacificPowerCompanyMember2024-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:RetainedEarningsMember2025-01-012025-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2025-01-012025-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:CommonStockMember2025-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2025-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:RetainedEarningsMember2025-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-03-310001081316bhe:SierraPacificPowerCompanyMember2025-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:CommonStockMember2025-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2025-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:RetainedEarningsMember2025-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:RetainedEarningsMember2026-01-012026-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2026-01-012026-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:CommonStockMember2026-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:AdditionalPaidInCapitalMember2026-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:RetainedEarningsMember2026-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MinimumMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMembersrt:MaximumMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:RegulatedOperationMemberus-gaap:ElectricityGenerationPlantNonNuclearMembersrt:MinimumMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:ElectricityGenerationPlantNonNuclearMembersrt:MaximumMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:ElectricityGenerationPlantNonNuclearMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:ElectricityGenerationPlantNonNuclearMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:RegulatedOperationMemberus-gaap:NaturalGasProcessingPlantMembersrt:MinimumMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:NaturalGasProcessingPlantMembersrt:MaximumMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:NaturalGasProcessingPlantMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:RegulatedOperationMemberus-gaap:NaturalGasProcessingPlantMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:OtherNoncurrentAssetsMemberbhe:NVEnergyInc.Memberus-gaap:PensionPlansDefinedBenefitMembercountry:USbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:OtherNoncurrentAssetsMemberbhe:NVEnergyInc.Memberus-gaap:PensionPlansDefinedBenefitMembercountry:USbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:OtherCurrentLiabilitiesMemberbhe:NVEnergyInc.Memberus-gaap:OtherPensionPlansDefinedBenefitMembercountry:USbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:OtherCurrentLiabilitiesMemberbhe:NVEnergyInc.Memberus-gaap:OtherPensionPlansDefinedBenefitMembercountry:USbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:OtherNoncurrentLiabilitiesMemberbhe:NVEnergyInc.Memberus-gaap:OtherPensionPlansDefinedBenefitMembercountry:USbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:OtherNoncurrentLiabilitiesMemberbhe:NVEnergyInc.Memberus-gaap:OtherPensionPlansDefinedBenefitMembercountry:USbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:OtherNoncurrentAssetsMemberbhe:NVEnergyInc.Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembercountry:USbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:OtherNoncurrentAssetsMemberbhe:NVEnergyInc.Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembercountry:USbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentAssetsMemberus-gaap:NondesignatedMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberbhe:DerivativeLiabilityCurrentMemberus-gaap:NondesignatedMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentLiabilitiesMemberus-gaap:NondesignatedMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:NondesignatedMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentAssetsMemberus-gaap:NondesignatedMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberbhe:DerivativeLiabilityCurrentMemberus-gaap:NondesignatedMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:OtherNoncurrentLiabilitiesMemberus-gaap:NondesignatedMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:NondesignatedMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:CommodityContractMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-12-310001081316us-gaap:CommodityContractMemberbhe:NaturalGasPurchasesMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberbhe:NaturalGasPurchasesMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:CommodityContractMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316bhe:SierraPacificPowerCompanyMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:CommodityMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:CommodityMemberbhe:SierraPacificPowerCompanyMember2024-12-310001081316us-gaap:CommodityMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:CommodityMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316us-gaap:CommodityMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CommodityMemberbhe:SierraPacificPowerCompanyMember2025-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:SierraPacificPowerCompanyMember2025-12-310001081316bhe:SierraPacificPowerCompanyMemberbhe:CustomerRefundMember2026-03-310001081316bhe:SierraPacificPowerCompanyMemberbhe:CustomerRefundMember2025-12-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:ResidentialMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:ResidentialMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:ResidentialMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:ResidentialMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:ResidentialMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:ResidentialMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:CommercialMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:CommercialMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:CommercialMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:CommercialMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:CommercialMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:CommercialMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:IndustrialMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:IndustrialMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:IndustrialMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:IndustrialMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:IndustrialMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:IndustrialMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:OtherMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:OtherMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:OtherMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:OtherMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:OtherMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:OtherMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledcustomerMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:DistributiononlyserviceMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:DistributiononlyserviceMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:DistributiononlyserviceMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:DistributiononlyserviceMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:DistributiononlyserviceMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:DistributiononlyserviceMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledanddistributionservicesonlycustomerMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledanddistributionservicesonlycustomerMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledanddistributionservicesonlycustomerMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedRetailElectricMemberus-gaap:RegulatedOperationMemberbhe:FullybundledanddistributionservicesonlycustomerMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:FullybundledanddistributionservicesonlycustomerMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:FullybundledanddistributionservicesonlycustomerMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316bhe:RegulatedwholesaletransmissionandotherMemberus-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedwholesaletransmissionandotherMemberus-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316bhe:RegulatedwholesaletransmissionandotherMemberus-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316bhe:RegulatedwholesaletransmissionandotherMemberus-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedwholesaletransmissionandotherMemberus-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316bhe:RegulatedwholesaletransmissionandotherMemberus-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:SierraPacificPowerCompanyMember2025-01-012025-03-310001081316bhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316bhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316bhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316bhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-01-012026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-01-012025-03-310001081316us-gaap:OperatingSegmentsMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:SierraPacificPowerCompanyMemberbhe:ElectricityRegulatedSegmentMember2025-12-310001081316us-gaap:OperatingSegmentsMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2026-03-310001081316us-gaap:OperatingSegmentsMemberbhe:SierraPacificPowerCompanyMemberbhe:NaturalGasRegulatedSegmentMember2025-12-310001081316us-gaap:CorporateNonSegmentMemberbhe:SierraPacificPowerCompanyMember2026-03-310001081316us-gaap:CorporateNonSegmentMemberbhe:SierraPacificPowerCompanyMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:NonrelatedPartyMember2026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:NonrelatedPartyMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:RelatedPartyMember2026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:RelatedPartyMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMember2025-01-012025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:MemberUnitsMember2024-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2024-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:NoncontrollingInterestMember2024-12-310001081316bhe:EasternEnergyGasHoldingsLLCMember2024-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:MemberUnitsMember2025-01-012025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:NoncontrollingInterestMember2025-01-012025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:MemberUnitsMember2025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:NoncontrollingInterestMember2025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMember2025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:MemberUnitsMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:NoncontrollingInterestMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:MemberUnitsMember2026-01-012026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:NoncontrollingInterestMember2026-01-012026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2026-01-012026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:MemberUnitsMember2026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:NoncontrollingInterestMember2026-03-310001081316bhe:CovePointLNGLPMemberus-gaap:VariableInterestEntityPrimaryBeneficiaryMemberus-gaap:GeneralPartnerMemberbhe:EasternEnergyGasHoldingsLLCMember2026-01-012026-03-310001081316bhe:CovePointLNGLPMemberus-gaap:VariableInterestEntityPrimaryBeneficiaryMemberus-gaap:LimitedPartnerMemberbhe:EasternEnergyGasHoldingsLLCMember2026-01-012026-03-310001081316bhe:IroquoisGasTransmissionSystemL.P.Memberbhe:EasternEnergyGasHoldingsLLCMember2026-01-012026-03-310001081316bhe:IroquoisGasTransmissionSystemL.P.Memberus-gaap:VariableInterestEntityPrimaryBeneficiaryMemberbhe:EasternEnergyGasHoldingsLLCMemberbhe:FederalEnergyRegulatoryCommissionMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MinimumMemberbhe:EasternEnergyGasHoldingsLLCMemberus-gaap:GasTransmissionEquipmentMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MaximumMemberbhe:EasternEnergyGasHoldingsLLCMemberus-gaap:GasTransmissionEquipmentMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMemberus-gaap:GasTransmissionEquipmentMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMemberus-gaap:GasTransmissionEquipmentMember2025-12-310001081316us-gaap:RegulatedOperationMembersrt:MinimumMemberbhe:EasternEnergyGasHoldingsLLCMemberbhe:StorageAssetsMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MaximumMemberbhe:EasternEnergyGasHoldingsLLCMemberbhe:StorageAssetsMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMemberbhe:StorageAssetsMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMemberbhe:StorageAssetsMember2025-12-310001081316us-gaap:RegulatedOperationMembersrt:MinimumMemberbhe:EasternEnergyGasHoldingsLLCMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2026-03-310001081316us-gaap:RegulatedOperationMembersrt:MaximumMemberbhe:EasternEnergyGasHoldingsLLCMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2025-12-310001081316us-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:UnregulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMemberbhe:LNGFacilityMember2026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMemberbhe:LNGFacilityMember2025-12-310001081316us-gaap:UnregulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316bhe:EasternGasTransmissionAndStorageIncMember2025-09-300001081316bhe:EasternGasTransmissionAndStorageIncMember2025-09-012025-09-300001081316bhe:EasternGasTransmissionAndStorageIncMember2026-01-310001081316bhe:EasternGasTransmissionAndStorageIncMember2026-01-012026-01-310001081316bhe:IroquoisGasTransmissionSystemL.P.Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316bhe:IroquoisGasTransmissionSystemL.P.Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:BankTimeDepositsMember2026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:BankTimeDepositsMember2025-12-310001081316us-gaap:PensionPlansDefinedBenefitMemberbhe:MidAmericanEnergyPensionPlanMemberbhe:EasternEnergyGasHoldingsLLCMember2026-01-012026-03-310001081316us-gaap:PensionPlansDefinedBenefitMemberbhe:MidAmericanEnergyPensionPlanMemberbhe:EasternEnergyGasHoldingsLLCMember2025-01-012025-03-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:ForeignExchangeContractMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:EquityFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternEnergyGasHoldingsLLCMember2026-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternEnergyGasHoldingsLLCMember2025-12-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasMemberus-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2025-01-012025-03-310001081316bhe:RegulatedWholesaleMemberus-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2026-01-012026-03-310001081316bhe:RegulatedWholesaleMemberus-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2025-01-012025-03-310001081316us-gaap:UnregulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2026-01-012026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:EasternEnergyGasHoldingsLLCMember2025-01-012025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMember2026-04-012026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMember2027-04-012026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2024-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2024-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AociAttributableToNoncontrollingInterestMember2024-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2025-01-012025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2025-01-012025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AociAttributableToNoncontrollingInterestMember2025-01-012025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-01-012025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AociAttributableToNoncontrollingInterestMember2025-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AociAttributableToNoncontrollingInterestMember2025-12-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2026-01-012026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2026-01-012026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AociAttributableToNoncontrollingInterestMember2026-01-012026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedDefinedBenefitPlansAdjustmentIncludingPortionAttributableToNoncontrollingInterestMember2026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AccumulatedGainLossCashFlowHedgeIncludingNoncontrollingInterestMember2026-03-310001081316bhe:EasternEnergyGasHoldingsLLCMemberus-gaap:AociAttributableToNoncontrollingInterestMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMember2025-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:NonrelatedPartyMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:NonrelatedPartyMember2025-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:RelatedPartyMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:RelatedPartyMember2025-12-310001081316bhe:EasternGasTransmissionAndStorageIncMember2025-01-012025-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:CommonStockMember2024-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:AdditionalPaidInCapitalMember2024-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:RetainedEarningsMember2024-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2024-12-310001081316bhe:EasternGasTransmissionAndStorageIncMember2024-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:RetainedEarningsMember2025-01-012025-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:CommonStockMember2025-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:AdditionalPaidInCapitalMember2025-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:RetainedEarningsMember2025-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-03-310001081316bhe:EasternGasTransmissionAndStorageIncMember2025-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:CommonStockMember2025-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:AdditionalPaidInCapitalMember2025-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:RetainedEarningsMember2025-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:RetainedEarningsMember2026-01-012026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2026-01-012026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:CommonStockMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:AdditionalPaidInCapitalMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:RetainedEarningsMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2026-03-310001081316srt:MinimumMemberbhe:EasternGasTransmissionAndStorageIncMemberus-gaap:GasTransmissionEquipmentMember2026-03-310001081316srt:MaximumMemberbhe:EasternGasTransmissionAndStorageIncMemberus-gaap:GasTransmissionEquipmentMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:GasTransmissionEquipmentMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:GasTransmissionEquipmentMember2025-12-310001081316srt:MinimumMemberbhe:EasternGasTransmissionAndStorageIncMemberbhe:StorageAssetsMember2026-03-310001081316srt:MaximumMemberbhe:EasternGasTransmissionAndStorageIncMemberbhe:StorageAssetsMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberbhe:StorageAssetsMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberbhe:StorageAssetsMember2025-12-310001081316srt:MinimumMemberbhe:EasternGasTransmissionAndStorageIncMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2026-03-310001081316srt:MaximumMemberbhe:EasternGasTransmissionAndStorageIncMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:OtherCapitalizedPropertyPlantAndEquipmentMember2025-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:BankTimeDepositsMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:BankTimeDepositsMember2025-12-310001081316us-gaap:PensionPlansDefinedBenefitMemberbhe:MidAmericanEnergyCompanyRetirementPlanMemberbhe:EasternGasTransmissionAndStorageIncMember2026-01-012026-03-310001081316us-gaap:PensionPlansDefinedBenefitMemberbhe:MidAmericanEnergyCompanyRetirementPlanMemberbhe:EasternGasTransmissionAndStorageIncMember2025-01-012025-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternGasTransmissionAndStorageIncMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternGasTransmissionAndStorageIncMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternGasTransmissionAndStorageIncMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:EasternGasTransmissionAndStorageIncMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternGasTransmissionAndStorageIncMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternGasTransmissionAndStorageIncMember2026-03-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternGasTransmissionAndStorageIncMember2026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:FairValueMeasurementsRecurringMember2026-03-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternGasTransmissionAndStorageIncMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternGasTransmissionAndStorageIncMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternGasTransmissionAndStorageIncMember2025-12-310001081316us-gaap:MoneyMarketFundsMemberus-gaap:FairValueMeasurementsRecurringMemberbhe:EasternGasTransmissionAndStorageIncMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Memberbhe:EasternGasTransmissionAndStorageIncMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternGasTransmissionAndStorageIncMember2025-12-310001081316us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Memberbhe:EasternGasTransmissionAndStorageIncMember2025-12-310001081316bhe:EasternGasTransmissionAndStorageIncMemberus-gaap:FairValueMeasurementsRecurringMember2025-12-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:EasternGasTransmissionAndStorageIncMember2026-03-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternGasTransmissionAndStorageIncMember2026-03-310001081316us-gaap:CarryingReportedAmountFairValueDisclosureMemberbhe:EasternGasTransmissionAndStorageIncMember2025-12-310001081316us-gaap:EstimateOfFairValueFairValueDisclosureMemberus-gaap:FairValueInputsLevel2Memberbhe:EasternGasTransmissionAndStorageIncMember2025-12-310001081316bhe:RegulatedRetailGasTransportationMemberus-gaap:RegulatedOperationMemberbhe:EasternGasTransmissionAndStorageIncMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasTransportationMemberus-gaap:RegulatedOperationMemberbhe:EasternGasTransmissionAndStorageIncMember2025-01-012025-03-310001081316bhe:RegulatedRetailGasStorageMemberus-gaap:RegulatedOperationMemberbhe:EasternGasTransmissionAndStorageIncMember2026-01-012026-03-310001081316bhe:RegulatedRetailGasStorageMemberus-gaap:RegulatedOperationMemberbhe:EasternGasTransmissionAndStorageIncMember2025-01-012025-03-310001081316bhe:RegulatedWholesaleMemberus-gaap:RegulatedOperationMemberbhe:EasternGasTransmissionAndStorageIncMember2026-01-012026-03-310001081316bhe:RegulatedWholesaleMemberus-gaap:RegulatedOperationMemberbhe:EasternGasTransmissionAndStorageIncMember2025-01-012025-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternGasTransmissionAndStorageIncMember2026-01-012026-03-310001081316us-gaap:RegulatedOperationMemberbhe:EasternGasTransmissionAndStorageIncMember2025-01-012025-03-310001081316us-gaap:UnregulatedOperationMemberbhe:EasternGasTransmissionAndStorageIncMember2026-01-012026-03-310001081316us-gaap:UnregulatedOperationMemberbhe:EasternGasTransmissionAndStorageIncMember2025-01-012025-03-310001081316bhe:EasternGasTransmissionAndStorageIncMember2026-04-012026-03-310001081316bhe:EasternGasTransmissionAndStorageIncMember2027-04-012026-03-31

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended March 31, 2026

or

☐ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from ______ to _______

Exact name of registrant as specified in its charter

State or other jurisdiction of incorporation or organization

Commission

Address of principal executive offices

IRS Employer

File Number

Registrant's telephone number, including area code

Identification No.

001-14881

BERKSHIRE HATHAWAY ENERGY COMPANY

94-2213782

(An Iowa Corporation)

1615 Locust Street

Des Moines, Iowa 50309-3037

515-242-4300

001-05152

PACIFICORP

93-0246090

(An Oregon Corporation)

825 N.E. Multnomah Street

Portland, Oregon 97232

888-221-7070

333-90553

MIDAMERICAN FUNDING, LLC

47-0819200

(An Iowa Limited Liability Company)

1615 Locust Street

Des Moines, Iowa 50309-3037

515-242-4300

333-15387

MIDAMERICAN ENERGY COMPANY

42-1425214

(An Iowa Corporation)

1615 Locust Street

Des Moines, Iowa 50309-3037

515-242-4300

000-52378

NEVADA POWER COMPANY

88-0420104

(A Nevada Corporation)

6226 West Sahara Avenue

Las Vegas, Nevada 89146

702-402-5000

000-00508

SIERRA PACIFIC POWER COMPANY

88-0044418

(A Nevada Corporation)

6100 Neil Road

Reno, Nevada 89511

775-834-4011

001-37591

EASTERN ENERGY GAS HOLDINGS, LLC

46-3639580

(A Virginia Limited Liability Company)

10700 Energy Way

Glen Allen, Virginia 23060

804-613-5100

333-266049

EASTERN GAS TRANSMISSION AND STORAGE, INC.

55-0629203

(A Delaware Corporation)

10700 Energy Way

Glen Allen, Virginia 23060

804-613-5100

N/A

(Former name, former address and former fiscal year, if changed since last report)

---

Registrant			Securities registered pursuant to Section 12(b) of the Act:
BERKSHIRE HATHAWAY ENERGY COMPANY			None
PACIFICORP			None
MIDAMERICAN FUNDING, LLC			None
MIDAMERICAN ENERGY COMPANY			None
NEVADA POWER COMPANY			None
SIERRA PACIFIC POWER COMPANY			None
EASTERN ENERGY GAS HOLDINGS, LLC			None
EASTERN GAS TRANSMISSION AND STORAGE, INC.			None

Registrant			Name of exchange on which registered:
BERKSHIRE HATHAWAY ENERGY COMPANY			None
PACIFICORP			None
MIDAMERICAN FUNDING, LLC			None
MIDAMERICAN ENERGY COMPANY			None
NEVADA POWER COMPANY			None
SIERRA PACIFIC POWER COMPANY			None
EASTERN ENERGY GAS HOLDINGS, LLC			None
EASTERN GAS TRANSMISSION AND STORAGE, INC.			None

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.

Registrant			Yes			No
BERKSHIRE HATHAWAY ENERGY COMPANY			☒
PACIFICORP			☒
MIDAMERICAN FUNDING, LLC						☒
MIDAMERICAN ENERGY COMPANY			☒
NEVADA POWER COMPANY			☒
SIERRA PACIFIC POWER COMPANY			☒
EASTERN ENERGY GAS HOLDINGS, LLC			☒
EASTERN GAS TRANSMISSION AND STORAGE, INC.			☒

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files). Yes  x  No  o

---

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.

Registrant

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company

Emerging growth company

BERKSHIRE HATHAWAY ENERGY COMPANY

☐

☐

☒

☐

☐

PACIFICORP

☐

☐

☒

☐

☐

MIDAMERICAN FUNDING, LLC

☐

☐

☒

☐

☐

MIDAMERICAN ENERGY COMPANY

☐

☐

☒

☐

☐

NEVADA POWER COMPANY

☐

☐

☒

☐

☐

SIERRA PACIFIC POWER COMPANY

☐

☐

☒

☐

☐

EASTERN ENERGY GAS HOLDINGS, LLC

☐

☐

☒

☐

☐

EASTERN GAS TRANSMISSION AND STORAGE, INC.

☐

☐

☒

☐

☐

If an emerging growth company, indicate by check mark if the registrants have 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.  o

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

Yes  ☐  No  x

All shares of outstanding common stock of Berkshire Hathaway Energy Company are held by its parent company, Berkshire Hathaway Inc. As of April 30, 2026, 1 share of common stock, no par value, was outstanding.

All shares of outstanding common stock of PacifiCorp are indirectly held by Berkshire Hathaway Energy Company. As of April 30, 2026, 357,060,915 shares of common stock, no par value, were outstanding.

All of the member's equity of MidAmerican Funding, LLC is held by its parent company, Berkshire Hathaway Energy Company, as of April 30, 2026.

All shares of outstanding common stock of MidAmerican Energy Company are held by its parent company, MHC Inc., which is a direct, wholly owned subsidiary of MidAmerican Funding, LLC. As of April 30, 2026, 70,980,203 shares of common stock, no par value, were outstanding.

All shares of outstanding common stock of Nevada Power Company are held by its parent company, NV Energy, Inc., which is an indirect, wholly owned subsidiary of Berkshire Hathaway Energy Company. As of April 30, 2026, 1,000 shares of common stock, $1.00 stated value, were outstanding.

All shares of outstanding common stock of Sierra Pacific Power Company are held by its parent company, NV Energy, Inc. As of April 30, 2026, 1,000 shares of common stock, $3.75 par value, were outstanding.

All of the member's equity of Eastern Energy Gas Holdings, LLC is held indirectly by its parent company, Berkshire Hathaway Energy Company, as of April 30, 2026.

All shares of outstanding common stock of Eastern Gas Transmission and Storage, Inc. are held by its parent company, Eastern Energy Gas Holdings, LLC, which is an indirect, wholly owned subsidiary of Berkshire Hathaway Energy Company. As of April 30, 2026, 60,101 shares of common stock, $10,000 par value, were outstanding.

This combined Form 10-Q is separately filed by Berkshire Hathaway Energy Company, PacifiCorp, MidAmerican Funding, LLC, MidAmerican Energy Company, Nevada Power Company, Sierra Pacific Power Company, Eastern Energy Gas Holdings, LLC and Eastern Gas Transmission and Storage, Inc. Information contained herein relating to any individual company is filed by such company on its own behalf. Each company makes no representation as to information relating to the other companies.

---

TABLE OF CONTENTS

 

PART I

 

Item 1.			Financial Statements			1
Item 2.			Management's Discussion and Analysis of Financial Condition and Results of Operations			1
Item 3.			Quantitative and Qualitative Disclosures About Market Risk			197
Item 4.			Controls and Procedures			197

 

PART II

 

Item 1.			Legal Proceedings			198
Item 1A.			Risk Factors			202
Item 2.			Unregistered Sales of Equity Securities and Use of Proceeds			202
Item 3.			Defaults Upon Senior Securities			202
Item 4.			Mine Safety Disclosures			203
Item 5.			Other Information			203
Item 6.			Exhibits			203
Signatures						207

i

---

Definition of Abbreviations and Industry Terms

When used in Forward-Looking Statements, Part I - Items 2 through 3, and Part II - Items 1 through 6, the following terms have the definitions indicated.

Berkshire Hathaway Energy Company and Related Entities
BHE						Berkshire Hathaway Energy Company
Berkshire Hathaway						Berkshire Hathaway Inc.
Berkshire Hathaway Energy or the Company						Berkshire Hathaway Energy Company and its subsidiaries
PacifiCorp						PacifiCorp and its subsidiaries
MidAmerican Funding						MidAmerican Funding, LLC and its subsidiaries
MidAmerican Energy						MidAmerican Energy Company
NV Energy						NV Energy, Inc. and its subsidiaries
Nevada Power						Nevada Power Company and its subsidiaries
Sierra Pacific						Sierra Pacific Power Company and its subsidiaries
Nevada Utilities						Nevada Power Company and its subsidiaries and Sierra Pacific Power Company and its subsidiaries
Eastern Energy Gas						Eastern Energy Gas Holdings, LLC and its subsidiaries
EGTS						Eastern Gas Transmission and Storage, Inc. and its subsidiaries
Registrants						Berkshire Hathaway Energy Company, PacifiCorp and its subsidiaries, MidAmerican Funding, LLC and its subsidiaries, MidAmerican Energy Company, Nevada Power Company and its subsidiaries, Sierra Pacific Power Company and its subsidiaries, Eastern Energy Gas Holdings, LLC and its subsidiaries and Eastern Gas Transmission and Storage, Inc. and its subsidiaries
Northern Powergrid						Northern Powergrid Holdings Company and its subsidiaries
BHE Pipeline Group						BHE GT&S, LLC, Northern Natural Gas Company and Kern River Gas Transmission Company
BHE GT&S						BHE GT&S, LLC and its subsidiaries
Northern Natural Gas						Northern Natural Gas Company
Kern River						Kern River Gas Transmission Company
BHE Transmission						BHE Canada Holdings Corporation and BHE U.S. Transmission, LLC
BHE Canada						BHE Canada Holdings Corporation and its subsidiaries
AltaLink						AltaLink, L.P. and its subsidiaries
BHE U.S. Transmission						BHE U.S. Transmission, LLC and its subsidiaries
BHE Renewables						BHE Renewables, LLC and its subsidiaries
HomeServices						HomeServices of America, Inc. and its subsidiaries
Utilities						PacifiCorp and its subsidiaries, MidAmerican Energy Company, Nevada Power Company and its subsidiaries and Sierra Pacific Power Company and its subsidiaries
Cove Point						Cove Point LNG, LP
Iroquois						Iroquois Gas Transmission System, L.P.

ii

---

Certain Industry Terms
2020 Wildfires						Wildfires in Oregon and Northern California that occurred in September 2020
2022 McKinney Fire						A wildfire that began in the Oak Knoll Ranger District of the Klamath National Forest in Siskiyou County, California in July 2022
Wildfires						2020 Wildfires and 2022 McKinney Fire
AFUDC						Allowance for Funds Used During Construction
AUC						Alberta Utilities Commission
CCR						Coal Combustion Residuals
CPUC						California Public Utilities Commission
D.C. Circuit						United States Court of Appeals for the District of Columbia Circuit
Dth						Decatherm
EPA						United States Environmental Protection Agency
FERC						Federal Energy Regulatory Commission
GAAP						Accounting principles generally accepted in the United States of America
GTA						General Tariff Application
GWh						Gigawatt Hour
IPUC						Idaho Public Utilities Commission
IRP						Integrated Resource Plan
James						A class action complaint filed against PacifiCorp on September 30, 2020, captioned Jeanyne James et al. v. PacifiCorp, in Multnomah County Circuit Court Oregon and the associated consolidated cases
kV						Kilovolt
LNG						Liquefied Natural Gas
MW						Megawatt
MWh						Megawatt Hour
NAAQS						National Ambient Air Quality Standards
NOx						Nitrogen Oxides
OPUC						Oregon Public Utility Commission
PTC						Production Tax Credit
PUCN						Public Utilities Commission of Nevada
RFP						Request for Proposals
RPS						Renewable Portfolio Standards
SEC						United States Securities and Exchange Commission
SIP						State Implementation Plan
SO2						Sulfur Dioxide
UPSC						Utah Public Service Commission
WPSC						Wyoming Public Service Commission
WUTC						Washington Utilities and Transportation Commission

iii

---

Forward-Looking Statements

This report contains statements that do not directly or exclusively relate to historical facts. These statements are "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements can typically be identified by the use of forward-looking words, such as "will," "may," "could," "project," "believe," "anticipate," "expect," "estimate," "continue," "intend," "potential," "plan," "forecast" and similar terms. These statements are based upon the relevant Registrant's current intentions, estimates, assumptions, expectations and beliefs and are subject to risks, uncertainties and other important factors. Many of these factors are outside the control of each Registrant and could cause actual results to differ materially from those expressed or implied by such forward-looking statements. These factors include, among others:

•general economic, political and business conditions, as well as changes in, and compliance with, laws and regulations, including trade policy, tariffs and income tax reform, initiatives regarding deregulation and restructuring of the utility industry and reliability and safety standards, affecting the respective Registrant's operations or related industries;

•changes in, and compliance with, environmental laws, regulations, decisions and policies, whether directed towards protection of environmental resources, present and future climate considerations or social justice concerns that could, among other items, increase operating and capital costs, reduce facility output, accelerate or decelerate facility retirements or delay facility construction or acquisition;

•the outcome of regulatory rate reviews and other proceedings conducted by regulatory agencies or other governmental and legal bodies and the respective Registrant's ability to recover costs through rates in a timely manner or at all;

•changes in economic, industry, competition or weather conditions, as well as demographic trends, new technologies and various conservation, energy efficiency and private generation measures and programs, that could affect customer growth and usage, electricity and natural gas supply or the respective Registrant's ability to obtain long-term contracts with customers and suppliers;

•performance, availability and ongoing operation of the respective Registrant's facilities, including facilities not operated by the Registrants, due to the impacts of market conditions, outages and associated repairs, transmission constraints, weather, including wind, solar and hydroelectric conditions, and operating conditions;

•the effects of catastrophic and other unforeseen events, which may be caused by factors beyond the control of each respective Registrant or by a breakdown or failure of the Registrants' operating assets, including severe storms, floods, fires, extreme temperature events, wind events, earthquakes, explosions, landslides, electromagnetic pulses, mining incidents, costly litigation, wars, terrorism, pandemics, embargoes, and cyber security attacks, data security breaches, disruptions, or other malicious acts;

•the risks and uncertainties associated with wildfires that have occurred, are occurring or may occur in the respective Registrant's service territory; the damage caused by such wildfires; the extent of the respective Registrant's liability in connection with such wildfires (including the risk that the respective Registrant may be found liable for damages regardless of fault); investigations into such wildfires; the outcomes of any legal proceedings, demands or similar actions initiated against the respective Registrant; the risk that the respective Registrant is not able to recover losses from insurance or through rates; and the effect of such wildfires, investigations and legal proceedings on the respective Registrant's financial condition and reputation;

•the outcomes of legal or other actions, including the effects of amounts to be paid to complainants as a result of settlements or final legal determinations and bonding requirements related to legal judgments that have been appealed, including potential collateral triggers, associated with the Wildfires, which could have a material adverse effect on PacifiCorp's financial condition and could limit PacifiCorp's ability to access capital on terms commensurate with historical transactions or at all and could impact PacifiCorp's liquidity, cash flows and capital expenditure plans;

•the respective Registrant's ability to reduce wildfire threats and improve safety, including the ability to comply with the targets and metrics outlined in its wildfire prevention plans; to retain or contract for the workforce necessary to execute its wildfire prevention plans; the effectiveness of its system hardening; ability to achieve vegetation management targets; and the cost of these programs and the timing and outcome of any proceeding to recover such costs through rates;

•the ability to economically obtain insurance coverage, or any insurance coverage at all, sufficient to cover losses arising from catastrophic events, such as wildfires;

•a high degree of variance between actual and forecasted load or generation that could impact a Registrant's hedging strategy and the cost of balancing its generation resources with its retail load obligations;

iv

---

•changes in prices, availability and demand for wholesale electricity, coal, natural gas, other fuel sources and fuel transportation that could have a significant impact on generating capacity and energy costs;

•the financial condition, creditworthiness and operational stability of the respective Registrant's significant customers and suppliers;

•changes in business strategy or development plans;

•availability, terms and deployment of capital, including reductions in demand for investment-grade commercial paper, debt securities and other sources of debt financing and volatility in interest rates and credit spreads;

•changes in the respective Registrant's credit ratings, changes in rating methodology. placement on negative outlook or credit watch and downgrades to below investment grade;

•risks relating to nuclear generation, including unique operational, closure and decommissioning risks;

•hydroelectric conditions and the cost, feasibility and eventual outcome of hydroelectric relicensing proceedings;

•the impact of certain contracts used to mitigate or manage volume, price and interest rate risk, including increased collateral requirements, and changes in commodity prices, interest rates and other conditions that affect the fair value of certain contracts;

•the impact of inflation on costs and the ability of the respective Registrants to recover such costs in regulated rates;

•fluctuations in foreign currency exchange rates, primarily the British pound and the Canadian dollar;

•increases in employee healthcare costs;

•the impact of investment performance, certain participant elections such as lump sum distributions and changes in interest rates, legislation, healthcare cost trends, mortality, morbidity on pension and other postretirement benefits expense and funding requirements;

•changes in the residential real estate brokerage, mortgage and franchising industries, regulations that could affect brokerage, mortgage and franchising transactions and the outcomes of legal or other actions and the effects of amounts to be paid to complainants as a result of settlements or final legal determinations;

•the ability to successfully integrate future acquired operations into a Registrant's business;

•the ability to successfully close on planned dispositions and the ultimate regulatory treatment of amounts related to such transactions;

•the impact of supply chain disruptions and workforce availability on the respective Registrant's ongoing operations and its ability to timely complete construction projects;

•unanticipated construction delays, changes in costs, receipt of required permits and authorizations, ability to fund capital projects and other factors that could affect future facilities and infrastructure additions;

•the availability and price of natural gas and LNG in applicable geographic regions and demand for natural gas and LNG supply;

•the impact of new accounting guidance or changes in current accounting estimates and assumptions on the financial results of the respective Registrants; and

•other business or investment considerations that may be disclosed from time to time in the Registrants' filings with the SEC or in other publicly disseminated written documents.

Further details of the potential risks and uncertainties affecting the Registrants are described in the Registrants' filings with the SEC, including Part II, Item 1A and other discussions contained in this Form 10-Q. Each Registrant undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The foregoing factors should not be construed as exclusive.

v

---

Item 1.Financial Statements

Berkshire Hathaway Energy Company and its subsidiaries						3
PacifiCorp and its subsidiaries						48
MidAmerican Energy Company						78
MidAmerican Funding, LLC and its subsidiaries						94
Nevada Power Company and its subsidiaries						115
Sierra Pacific Power Company and its subsidiaries						136
Eastern Energy Gas Holdings, LLC and its subsidiaries						160
Eastern Gas Transmission and Storage, Inc. and its subsidiaries						180

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

Berkshire Hathaway Energy Company and its subsidiaries						32
PacifiCorp and its subsidiaries						69
MidAmerican Funding, LLC and its subsidiaries and MidAmerican Energy Company						106
Nevada Power Company and its subsidiaries						129
Sierra Pacific Power Company and its subsidiaries						151
Eastern Energy Gas Holdings, LLC and its subsidiaries						176
Eastern Gas Transmission and Storage, Inc. and its subsidiaries						194

1

---

Berkshire Hathaway Energy Company and its subsidiaries

Consolidated Financial Section

2

---

PART I

Item 1.Financial Statements

Report of Independent Registered Public Accounting Firm						4
Consolidated Balance Sheets						5
Consolidated Statements of Operations						7
Consolidated Statements of Comprehensive Income						8
Consolidated Statements of Changes in Equity						9
Consolidated Statements of Cash Flows						10
Notes to Consolidated Financial Statements
General						11
New Accounting Pronouncements						12
Dispositions						12
Property, Plant and Equipment, Net						14
Investments and Restricted Cash and Cash Equivalents and Investments						15
Recent Financing Transactions						16
Income Taxes						17
Employee Benefit Plans						19
Fair Value Measurements						20
Commitments and Contingencies						22
Revenue from Contracts with Customers						27
Components of Accumulated Other Comprehensive Loss, Net						28
Segment Information						29

3

---

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

Berkshire Hathaway Energy Company

Results of Review of Interim Financial Information

We have reviewed the accompanying consolidated balance sheet of Berkshire Hathaway Energy Company and subsidiaries (the "Company") as of March 31, 2026, the related consolidated statements of operations, comprehensive income, changes in equity, and cash flows for the three-month periods ended March 31, 2026 and 2025, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of the Company as of December 31, 2025, and the related consolidated statements of operations, comprehensive income, changes in equity, and cash flows for the year then ended (not presented herein); and in our report dated February 27, 2026, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2025, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of the Company's management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/ Deloitte & Touche LLP

Des Moines, Iowa

May 1, 2026

4

---

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions)

			As of
			March 31,						December 31,
			2026						2025
ASSETS
Current assets:
Cash and cash equivalents			$	4,203					$	1,695
Investments and restricted cash and cash equivalents			231						254
Trade receivables, net			2,560						2,678
Income taxes receivable			1,048						291
Inventories			2,086						2,105
Mortgage loans held for sale			722						698
Regulatory assets			573						892
Assets held for sale (Note 3)			1,994						—
Other current assets			1,195						1,024
Total current assets			14,612						9,637
Property, plant and equipment, net			111,566						112,368
Goodwill			11,400						11,521
Regulatory assets			3,898						3,929
Investments and restricted cash and cash equivalents and investments			7,364						7,608
Other assets			3,189						3,264
Total assets			$	152,029					$	148,327

The accompanying notes are an integral part of these consolidated financial statements.

5

---

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited) (continued)

(Amounts in millions, except share amounts)

			As of
			March 31,						December 31,
			2026						2025
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable			$	2,923					$	3,389
Accrued interest			855						797
Accrued property, income and other taxes			764						745
Accrued employee expenses			409						345
Short-term debt			1,005						1,997
Current portion of long-term debt			1,257						1,455
Wildfires liabilities (Note 10)			160						734
Liabilities held for sale (Note 3)			249						—
Other current liabilities			1,893						1,930
Total current liabilities			9,515						11,392
BHE senior debt			11,462						11,461
Subsidiary senior debt			45,500						42,759
Subsidiary junior subordinated debt			3,266						1,584
Regulatory liabilities			6,585						6,772
Deferred income taxes			13,119						12,999
Wildfires liabilities (Note 10)			417						427
Other long-term liabilities			5,873						5,624
Total liabilities			95,737						93,018
Commitments and contingencies (Note 10)
Equity:
BHE shareholder's equity:
Preferred stock - 100,000,000 shares authorized, $0.01 par value, — and — shares issued and outstanding			—						—
Common stock - 100 shares authorized, no par value, 1 share issued and outstanding			—						—
Additional paid-in capital			5,563						5,558
Retained earnings			51,465						50,351
Accumulated other comprehensive loss, net			(1,976)						(1,844)
Total BHE shareholder's equity			55,052						54,065
Noncontrolling interests			1,240						1,244
Total equity			56,292						55,309
Total liabilities and equity			$	152,029					$	148,327

The accompanying notes are an integral part of these consolidated financial statements.

6

---

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

									Three-Month Periods
									Ended March 31,
															2026						2025
Operating revenue:
Energy															$	5,810					$	5,506
Real estate															862						860
Total operating revenue															6,672						6,366
Operating expenses:
Energy:
Cost of sales															1,670						1,531
Operations and maintenance															1,298						1,249
Depreciation and amortization															1,126						1,106
Property and other taxes															241						226
Real estate															879						871
Total operating expenses															5,214						4,983
Operating income															1,458						1,383
Other income (expense):
Interest expense															(746)						(686)
Capitalized interest															45						40
Allowance for equity funds															80						66
Interest and dividend income															54						62
(Losses) gains on marketable securities, net															(5)						103
Other, net															(8)						(15)
Total other income (expense)															(580)						(430)
Income before income tax expense (benefit) and equity income (loss)															878						953
Income tax expense (benefit)															(430)						(399)
Equity income (loss)															(134)						(120)
Net income															1,174						1,232
Net income attributable to noncontrolling interests															60						45
Net income attributable to BHE shareholders															1,114						1,187
Preferred dividends															—						3
Earnings on common shares															$	1,114					$	1,184

The accompanying notes are an integral part of these consolidated financial statements.

 

7

---

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

(Amounts in millions)

									Three-Month Periods
									Ended March 31,
															2026						2025
Net income															$	1,174					$	1,232
Other comprehensive (loss) income, net of tax:
Unrecognized amounts on retirement benefits, net of tax of $7 and $2															17						—
Foreign currency translation adjustment															(143)						169
Unrealized losses on cash flow hedges, net of tax of $(4) and $(2)															(6)						(6)
Total other comprehensive (loss) income, net of tax															(132)						163
Comprehensive income															1,042						1,395
Comprehensive income attributable to noncontrolling interests															60						45
Comprehensive income attributable to BHE shareholders															$	982					$	1,350

The accompanying notes are an integral part of these consolidated financial statements.

8

---

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Unaudited)

(Amounts in millions)

			BHE Shareholder's Equity
																											Accumulated
															Additional												Other
			Preferred						Common						Paid-in						Retained						Comprehensive						Noncontrolling						Total
			Stock						Stock						Capital						Earnings						Loss, Net						Interests						Equity
Balance, December 31, 2024			$	481					$	—					$	5,558					$	46,311					$	(2,341)					$	1,280					$	51,289
Net income			—						—						—						1,187						—						45						1,232
Other comprehensive income			—						—						—						—						163						—						163
Preferred stock redemptions			(481)						—						—						—						—						—						(481)
Preferred stock dividend			—						—						—						(3)						—						—						(3)
Distributions			—						—						—						—						—						(46)						(46)
Other equity transactions			—						—						—						(2)						—						(3)						(5)
Balance, March 31, 2025			$	—					$	—					$	5,558					$	47,493					$	(2,178)					$	1,276					$	52,149

Balance, December 31, 2025			$	—					$	—					$	5,558					$	50,351					$	(1,844)					$	1,244					$	55,309
Net income			—						—						—						1,114						—						60						1,174
Other comprehensive loss			—						—						—						—						(132)						—						(132)
Distributions			—						—						—						—						—						(68)						(68)
Other equity transactions			—						—						5						—						—						4						9
Balance, March 31, 2026			$	—					$	—					$	5,563					$	51,465					$	(1,976)					$	1,240					$	56,292

The accompanying notes are an integral part of these consolidated financial statements.

9

---

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Cash flows from operating activities:
Net income			$	1,174					$	1,232
Adjustments to reconcile net income to net cash flows from operating activities:
Losses (gains) on marketable securities, net			5						(103)
Depreciation and amortization			1,135						1,116
Allowance for equity funds			(80)						(66)
Equity (income) loss, net of distributions			146						153
Net power cost deferrals			22						(88)
Amortization of net power cost deferrals			236						220
Other changes in regulatory assets and liabilities			9						(13)
Deferred income taxes and investment tax credits, net			333						(92)
Other, net			41						72
Changes in other operating assets and liabilities, net of effects from acquisitions:
Trade receivables and other assets			(113)						107
Derivative collateral, net			(53)						10
Pension and other postretirement benefit plans			(2)						(1)
Accrued property, income and other taxes, net			(778)						(349)
Accounts payable and other liabilities			(128)						(161)
Wildfires insurance receivable			—						98
Wildfires liability			(584)						(114)
Net cash flows from operating activities			1,363						2,021
Cash flows from investing activities:
Capital expenditures			(2,418)						(2,128)
Purchases of marketable securities			(153)						(94)
Proceeds from sales of marketable securities			193						667
Equity method investments			(11)						(22)
Other, net			31						4
Net cash flows from investing activities			(2,358)						(1,573)
Cash flows from financing activities:
Preferred stock redemptions			—						(481)
Preferred dividends			—						(3)
Repayments of BHE senior debt			—						(400)
Proceeds from subsidiary debt			4,568						2,353
Repayments of subsidiary debt			(210)						(40)
Net repayments of short-term debt			(989)						(441)
Distributions to noncontrolling interests			(68)						(46)
Other, net			192						(17)
Net cash flows from financing activities			3,493						925
Effect of exchange rate changes			(7)						4
Net change in cash and cash equivalents and restricted cash and cash equivalents			2,491						1,377
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period			1,878						1,586
Cash and cash equivalents and restricted cash and cash equivalents at end of period			$	4,369					$	2,963

The accompanying notes are an integral part of these consolidated financial statements.

10

---

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    General

Berkshire Hathaway Energy Company ("BHE"), a wholly owned subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway"), is a holding company headquartered in Iowa that has investments in a highly diversified portfolio of locally managed and operated businesses principally engaged in the energy industry (collectively with its subsidiaries, the "Company").

The Company's operations are organized as eight business segments: PacifiCorp and its subsidiaries ("PacifiCorp"), MidAmerican Funding, LLC and its subsidiaries ("MidAmerican Funding") (which primarily consists of MidAmerican Energy Company ("MidAmerican Energy")), NV Energy, Inc. and its subsidiaries ("NV Energy") (which primarily consists of Nevada Power Company and its subsidiaries ("Nevada Power") and Sierra Pacific Power Company and its subsidiaries ("Sierra Pacific")), Northern Powergrid Holdings Company and its subsidiaries ("Northern Powergrid") (which primarily consists of Northern Powergrid (Northeast) plc and Northern Powergrid (Yorkshire) plc), BHE Pipeline Group, LLC and its subsidiaries (which primarily consists of BHE GT&S, LLC and its subsidiaries ("BHE GT&S"), Northern Natural Gas Company ("Northern Natural Gas") and Kern River Gas Transmission Company ("Kern River")), BHE Transmission (which consists of BHE Canada Holdings Corporation and its subsidiaries ("BHE Canada") (which primarily consists of AltaLink, L.P. and its subsidiaries ("AltaLink")), BHE U.S. Transmission, LLC and its subsidiaries) and BHE Montana, BHE Renewables, LLC and its subsidiaries ("BHE Renewables") and HomeServices of America, Inc. and its subsidiaries ("HomeServices"). The Company, through these locally managed and operated businesses, has investments in four utility companies in the U.S. serving customers in 11 states, two electricity distribution companies in Great Britain, five interstate natural gas pipeline companies and interests in a liquefied natural gas ("LNG") export, import and storage facility in the U.S., an electric transmission business in Canada, interests in electric transmission businesses in the U.S., a renewable energy business primarily investing in wind, solar, geothermal and hydroelectric projects, one of the largest residential real estate brokerage firms in the U.S. and a residential real estate brokerage franchise business in the U.S.

The accompanying Consolidated Financial Statements and Notes to Consolidated Financial Statements should be read in conjunction with the Company's Annual Report on Form 10-K for the year ended December 31, 2025. The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2026, and for the three-month periods ended March 31, 2026 and 2025. The results of operations for the three-month period ended March 31, 2026, are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in the Company's Annual Report on Form 10-K for the year ended December 31, 2025, describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in the Company's accounting policies or its assumptions regarding significant accounting estimates during the three-month period ended March 31, 2026. Refer to Note 10 for discussion of loss contingencies related to the Oregon and Northern California 2020 wildfires (the "2020 Wildfires") and the wildfire that began in the Oak Knoll Ranger District of the Klamath National Forest in Siskiyou County, California in July 2022 (the "2022 McKinney Fire"), collectively referred to as the "Wildfires."

11

---

(2)    New Accounting Pronouncements

In November 2024, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures Subtopic 220-40, "Disaggregation of Income Statement Expenses" which addresses requests from investors for more detailed information about certain expenses and requires disclosure of the amounts of purchases of inventory, employee compensation, depreciation and intangible asset amortization included in each relevant expense caption presented on the income statement. This guidance, as clarified in ASU 2025-01, is effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. Early adoption is permitted and should be applied on a prospective basis, however retrospective application is permitted. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

In December 2025, the FASB issued ASU No. 2025-10, Government Grants Topic 832, "Accounting for Government Grants Received by Business Entities" which establishes accounting for government grants received by an entity, including guidance for a grant related to an asset and a grant related to income. This guidance also requires, consistent with current disclosure requirements, that an entity provide disclosures including the nature of the government grant received, the accounting policies used to account for the grant, and significant terms and conditions of the grant. This guidance is effective for interim and annual reporting periods beginning after December 15, 2028. Early adoption is permitted and can be applied using either a modified prospective approach, a modified retrospective approach or a retrospective approach. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

(3)    Dispositions

On February 15, 2026, PacifiCorp and Portland General Electric Company and an affiliate of Portland General Electric Company (together, the "PGE Entities") entered into an Asset Purchase and Service Area Transfer Agreement (the "Sale Agreement") to sell to the PGE Entities certain PacifiCorp assets and liabilities associated with PacifiCorp's Washington operations for a sales price of $1.9 billion in cash plus additional cash consideration for the value of specified assets to be delivered at closing, subject to customary purchase price adjustments (the "Transaction").

The Transaction assets and liabilities are associated with PacifiCorp's retail service area in Washington and include certain related distribution assets and infrastructure, as well as PacifiCorp's Chehalis combined cycle natural gas-fueled generating facility located in Chehalis, Washington, Goodnoe Hills wind-powered generating facility located in Goldendale, Washington, and Marengo wind-powered generating facility located in Dayton, Washington.

The Transaction has been approved by PacifiCorp's board of directors but is subject to customary closing conditions including (i) the expiration or termination of the waiting period and other required approvals under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, and (ii) the receipt of all necessary approvals, waivers and rulings from the Federal Energy Regulatory Commission ("FERC") and each of PacifiCorp's six state public utility commissions. In March and April 2026, PacifiCorp filed for approval of the Transaction and associated disposition of assets with each of its state public utility commissions, requesting approval by March 1, 2027. PacifiCorp expects to file with the FERC in June 2026 under applicable sections of the Federal Power Act and expects approval will be received within the timeframe requested of the state public utility commissions. The Transaction is expected to close shortly after approvals are received.

The Sale Agreement contains certain termination rights, including if the Transaction is not consummated by August 15, 2027, (subject to a six month extension to the extent certain regulatory approvals have not been received as of such date), and provides that upon termination of the Sale Agreement under certain specified circumstances, the terminating party would be required to pay the other party a termination fee of $35 million.

As a result of the Transaction, the Company has presented the associated assets and liabilities as held for sale as of March 31, 2026, on the Consolidated Balance Sheets within current assets and current liabilities due to the expected timing of close of the Transaction. As the Transaction does not represent a strategic shift that will have a major impact on PacifiCorp's operations or financial results based on the scale of PacifiCorp's Washington operations and retail service territory relative to its overall operations and retail service territory, the Transaction does not qualify for presentation as discontinued operations.

12

---

As the carrying value of the associated assets and liabilities are less than fair value less costs to sell, no loss has been recorded as a result of the Transaction. PacifiCorp continues to depreciate the property, plant and equipment included in the Transaction as it will continue to operate the assets and serve PacifiCorp's Washington customers through closing of the Transaction, during which time it will continue to recover in retail rates the associated depreciation expense and return on investment, and the continued depreciation will be reflected in the carry-over basis of the assets upon closing.

The assets and liabilities held for sale as presented in Assets held for sale and Liabilities held for sale on the Consolidated Balance Sheets as of March 31, 2026, are as follows:

Assets held for sale:
Trade receivables, net						$	111
Property, plant and equipment, net:
Utility generation, transmission and distribution systems			1,997
Accumulated depreciation and amortization			(455)
Construction work-in-progress			46
Property, plant and equipment, net						1,588
Regulatory assets						154
Goodwill						89
Other assets						52
Total assets held for sale						$	1,994
Liabilities held for sale:
Regulatory liabilities						$	200
Other liabilities						49
Total liabilities held for sale						$	249

Regulatory assets include amounts associated with deferred net power costs and unrealized loss on regulated derivative contracts for which the underlying contracts will transfer to the Buyer. Other assets and other liabilities include inventories, certain prepaid expenses, derivative balances, lease balances, asset retirement obligation balances and transmission deposits. Regulatory liabilities include amounts associated with cost of removal and excess deferred income tax liability balances.

13

---

(4)    Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

									As of
			Depreciable						March 31,						December 31,
			Life						2026						2025
Regulated assets:
Utility generation, transmission and distribution systems			5-80 years						$	108,515					$	109,815
Interstate natural gas pipeline assets			3-80 years						21,495						21,334
									130,010						131,149
Accumulated depreciation and amortization									(40,416)						(40,365)
Regulated assets, net									89,594						90,784
Nonregulated assets:
Independent power plants			2-50 years						9,590						9,242
Cove Point LNG facility			40 years						3,475						3,476
Other assets			2-30 years						2,571						2,912
									15,636						15,630
Accumulated depreciation and amortization									(4,757)						(4,637)
Nonregulated assets, net									10,879						10,993
									100,473						101,777
Construction work-in-progress									11,093						10,591
Property, plant and equipment, net									$	111,566					$	112,368

Construction work-in-progress includes $9.9 billion as of March 31, 2026, and $9.5 billion as of December 31, 2025, related to the construction of regulated assets.

14

---

(5)    Investments and Restricted Cash and Cash Equivalents and Investments

Investments and restricted cash and cash equivalents and investments consists of the following (in millions):

			As of
			March 31,						December 31,
			2026						2025
Investments:
U.S. Treasury Bills			$	43					$	42
Company-owned life insurance			553						572
Other			342						386
Total investments			938						1,000
Equity method investments:
BHE Renewables tax equity investments			3,751						3,945
Electric Transmission Texas, LLC			856						835
Iroquois Gas Transmission System, L.P.			604						584
Other			321						336
Total equity method investments			5,532						5,700
Restricted cash and cash equivalents and investments:
Quad Cities Station nuclear decommissioning trust funds			959						979
Other restricted cash and cash equivalents			166						183
Total restricted cash and cash equivalents and investments			1,125						1,162
Total investments and restricted cash and cash equivalents and investments			$	7,595					$	7,862
Reflected as:
Other current assets			$	231					$	254
Noncurrent assets			7,364						7,608
Total investments and restricted cash and cash equivalents and investments			$	7,595					$	7,862

Investments

(Losses) gains on marketable securities, net recognized during the period consists of the following (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Unrealized losses recognized on marketable securities held at the reporting date															$	(8)					$	(8)
Net gains recognized on marketable securities sold during the period															3						111
(Losses) gains on marketable securities, net															$	(5)					$	103

15

---

Cash and Cash Equivalents and Restricted Cash and Cash Equivalents

Cash equivalents consist of funds invested in money market mutual funds, U.S. Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted cash and cash equivalents consist substantially of funds restricted for debt service obligations for certain of the Company's nonregulated renewable energy projects. A reconciliation of cash and cash equivalents and restricted cash and cash equivalents as presented on the Consolidated Statements of Cash Flows is outlined below and disaggregated by the line items in which they appear on the Consolidated Balance Sheets (in millions):

			As of
			March 31,						December 31,
			2026						2025
Cash and cash equivalents			$	4,203					$	1,695
Investments and restricted cash and cash equivalents			149						168
Investments and restricted cash and cash equivalents and investments			17						15
Total cash and cash equivalents and restricted cash and cash equivalents			$	4,369					$	1,878

(6)    Recent Financing Transactions

Long-Term Debt

Senior Debt

In February 2026, PacifiCorp issued $400 million of 4.25% First Mortgage Bonds due March 2029.

In March 2026, PacifiCorp issued $300 million of its 4.65% First Mortgage Bonds due April 2029, $550 million of its 5.10% First Mortgage Bonds due April 2031, $800 million of its 5.45% First Mortgage Bonds due April 2033, and $850 million of its 5.80% First Mortgage Bonds due April 2036.

Junior Subordinated Debt

In February 2026, PacifiCorp issued $1.1 billion of its 7.125% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due August 2056. PacifiCorp will pay interest on the junior subordinated notes at a rate of 7.125% through August 2031, subject to a reset every five years, not to reset below 7.125%.

In March 2026, Sierra Pacific issued $600 million of its 6.375% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due September 2056. Sierra Pacific will pay interest on the junior subordinated notes at a rate of 6.375% through September 2031, subject to a reset every five years not to reset below 6.375%.

16

---

Credit Facilities

In April 2026, PacifiCorp entered into a letter of credit agreement under which letters of credit will be made available solely to provide collateral support for surety bonds issued pursuant to a corresponding surety arrangement for supersedeas undertakings to secure the performance and stay enforcement of trial court judgments entered against PacifiCorp relating to the James case, in each case while such judgments remain pending appeal by PacifiCorp in the Oregon Court of Appeals or the Oregon Supreme Court. Refer to Note 10 for information regarding the Oregon Court of Appeals opinion issued in April 2026 associated with the James case. The letter of credit agreement provides for a two-year standby letter of credit facility for PacifiCorp in an aggregate stated amount of up to $2.55 billion. In conjunction with the letter of credit agreement, PacifiCorp entered into a committed surety facility set forth in a term sheet with an initial aggregate capacity of $2.55 billion, not to exceed availability under the letter of credit agreement, and related indemnity agreement under which the surety party is committed to issue surety bonds from time to time for PacifiCorp to secure the supersedeas undertakings described above. The surety facility must be fully secured by letters of credit. If 91 days prior to the applicable termination date of any letter of credit issued under the arrangements described above, any letter of credit obligations remain outstanding, PacifiCorp will be required to provide cash collateral to secure outstanding letter of credit obligations in an amount equal to 103% of such obligations. In April 2026, PacifiCorp received the necessary approvals from the Oregon Public Utility Commission and the Idaho Public Utilities Commission.

(7)    Income Taxes

The Company's provision for income taxes has been computed on a stand-alone basis. Berkshire Hathaway includes the Company in its consolidated U.S. federal and Iowa state income tax returns and the majority of the Company's U.S. federal income tax is remitted to or received from Berkshire Hathaway, pursuant to a tax allocation agreement. The Company had a current income tax receivable from Berkshire Hathaway of $1,053 million and $282 million for federal income tax as of March 31, 2026 and December 31, 2025, respectively. The Company received no net cash payments for federal income taxes from Berkshire Hathaway for each of the three-month periods ended March 31, 2026 and 2025.

17

---

A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income before income tax expense (benefit) is as follows (amounts in millions):

			Three-Month Periods
			Ended March 31,
			2026												2025
			Amount						Percent						Amount						Percent
U.S. federal statutory income tax rate			$	184					21.0		%				$	200					21.0		%
State and local income taxes, net of federal income tax			18						2.1						14						1.5
Foreign tax effects:
United Kingdom
Other			(2)						(0.2)						15						1.6
Canada
Foreign regulated flow-thru			(11)						(1.2)						(10)						(1.1)
Other			1						0.1						1						0.1
Effect of cross-border tax laws			—						—						(1)						(0.1)
Energy-related tax credits			(564)						(64.2)						(560)						(58.8)
Nontaxable or nondeductible items:
Equity earnings			(28)						(3.2)						(25)						(2.6)
Noncontrolling interest			(12)						(1.4)						(9)						(1.0)
Other, net			2						0.2						2						0.2
Changes in unrecognized tax benefits			1						0.1						1						0.1
Other adjustments:
Effects of ratemaking(1)			(19)						(2.3)						(25)						(2.6)
Other			—						—						(2)						(0.1)
Effective income tax rate			$	(430)					(49.0)		%				$	(399)					(41.8)		%

(1)Effects of ratemaking is primarily attributable to activity associated with excess deferred income taxes.

Energy-related tax credits relate primarily to production tax credits ("PTCs") from wind- and solar-powered generating facilities owned by MidAmerican Energy, PacifiCorp, NV Energy and BHE Renewables. Federal renewable electricity PTCs are earned as energy from qualifying wind- and solar-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind- and solar-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in-service.

18

---

(8)    Employee Benefit Plans

Domestic Operations

Net periodic benefit cost (credit) for the domestic pension and other postretirement benefit plans included the following components (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Pension:
Service cost															$	3					$	3
Interest cost															25						26
Expected return on plan assets															(31)						(30)
Net amortization															2						2
Net periodic benefit (credit) cost															$	(1)					$	1
Other postretirement:
Service cost															$	1					$	1
Interest cost															7						7
Expected return on plan assets															(10)						(9)
Net amortization															(1)						(1)
Net periodic benefit credit															$	(3)					$	(2)

Amounts other than the service cost for pension and other postretirement benefit plans are recorded in other, net on the Consolidated Statements of Operations. Employer contributions to the domestic pension and other postretirement benefit plans are expected to be $13 million and $4 million, respectively, during 2026. As of March 31, 2026, $3 million and $— million of contributions had been made to the domestic pension and other postretirement benefit plans, respectively.

Foreign Operations

Net periodic benefit cost (credit) for the United Kingdom pension plan included the following components (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Service cost															$	1					$	1
Interest cost															16						14
Expected return on plan assets															(21)						(20)
Net amortization															8						8
Net periodic benefit cost															$	4					$	3

Amounts other than the service cost for the United Kingdom pension plan are recorded in other, net on the Consolidated Statements of Operations. Employer contributions to the United Kingdom pension plan are expected to be £5 million during 2026. As of March 31, 2026, £1 million, or $2 million, of contributions had been made to the United Kingdom pension plan.

19

---

(9)    Fair Value Measurements

The carrying value of the Company's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. The Company has various financial assets and liabilities that are measured at fair value on the Consolidated Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

•Level 1 — Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date.

•Level 2 — Inputs include 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 that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).

•Level 3 — Unobservable inputs reflect the Company's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. The Company develops these inputs based on the best information available, including its own data.

The following table presents the Company's financial assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions):

			Input Levels for Fair Value Measurements
			Level 1						Level 2						Level 3						Other(1)						Total
As of March 31, 2026:
Assets:
Commodity derivatives			$	1					$	41					$	—					$	(4)					$	38
Foreign currency exchange rate derivatives			—						5						—						—						5
Interest rate derivatives			12						34						12						—						58
Mortgage loans held for sale			—						722						—						—						722
Money market mutual funds			3,986						—						—						—						3,986
Debt securities:
U.S. government obligations			330						—						—						—						330
Corporate obligations			—						127						—						—						127
Municipal obligations			—						2						—						—						2
Equity securities:
U.S. companies			522						—						—						—						522
International companies			9						—						—						—						9
Investment funds			243						—						—						—						243
			$	5,103					$	931					$	12					$	(4)					$	6,042
Liabilities:
Commodity derivatives			$	(15)					$	(136)					$	(67)					$	77					$	(141)
Interest rate derivatives			—						—						(2)						—						(2)
			$	(15)					$	(136)					$	(69)					$	77					$	(143)

20

---

						Input Levels for Fair Value Measurements
						Level 1						Level 2						Level 3						Other(1)						Total
As of December 31, 2025:
Assets:
Commodity derivatives						$	—					$	47					$	2					$	(8)					$	41
Foreign currency exchange rate derivatives						—						11						—						—						11
Interest rate derivatives						12						25						8						—						45
Mortgage loans held for sale						—						698						—						—						698
Money market mutual funds						1,469						—						—						—						1,469
Debt securities:
U.S. government obligations						326						—						—						—						326
Corporate obligations						—						133						—						—						133
Municipal obligations						—						2						—						—						2
Equity securities:
U.S. companies						549						—						—						—						549
International companies						9						—						—						—						9
Investment funds						283						—						—						—						283
						$	2,648					$	916					$	10					$	(8)					$	3,566
Liabilities:
Commodity derivatives						$	(13)					$	(169)					$	(56)					$	83					$	(155)
Interest rate derivatives						—						(3)						—						1						(2)
						$	(13)					$	(172)					$	(56)					$	84					$	(157)

(1)Represents netting under master netting arrangements and a net cash collateral receivable of $73 million and $76 million as of March 31, 2026, and December 31, 2025, respectively.

Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which the Company transacts. When quoted prices for identical contracts are not available, the Company uses forward price curves. Forward price curves represent the Company's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. The Company bases its forward price curves upon market price quotations, when available, or internally developed and commercial models, with internal and external fundamental data inputs. Market price quotations are obtained from independent brokers, exchanges, direct communication with market participants and actual transactions executed by the Company. Market price quotations are generally readily obtainable for the applicable term of the Company's outstanding derivative contracts; therefore, the Company's forward price curves reflect observable market quotes. Market price quotations for certain electricity and natural gas trading hubs are not as readily obtainable due to the length of the contract. Given that limited market data exists for these contracts, as well as for those contracts that are not actively traded, the Company uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The estimated fair value of these derivative contracts is a function of the underlying forward commodity prices, interest rates, currency rates, related volatility, counterparty creditworthiness and duration of contracts.

The Company's mortgage loans held for sale are valued based on independent quoted market prices, where available, or the prices of other mortgage whole loans with similar characteristics. As necessary, these prices are adjusted for typical securitization activities, including servicing value, portfolio composition, market conditions and liquidity.

The Company's investments in money market mutual funds and debt and equity securities are stated at fair value. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. In the absence of a quoted market price or net asset value of an identical security, the fair value is determined using pricing models or net asset values based on observable market inputs and quoted market prices of securities with similar characteristics.

21

---

The following table reconciles the beginning and ending balances of the Company's financial assets and liabilities measured at fair value on a recurring basis using significant Level 3 inputs (in millions). Transfers out of Level 3 occur primarily due to increased price observability.

									Three-Month Periods
									Ended March 31,
																					Interest
															Commodity						Rate
															Derivatives						Derivatives
2026:
Beginning balance															$	(54)					$	8
Changes included in earnings(1)															—						2
Changes in fair value recognized in net regulatory assets															(19)						—
Settlements															6						—
Ending balance															$	(67)					$	10

2025:
Beginning balance															$	(72)					$	5
Changes included in earnings(1)															—						9
Changes in fair value recognized in net regulatory assets															(31)						—
Settlements															11						—
Ending balance															$	(92)					$	14

(1)Changes included in earnings for interest rate derivatives are reported net of amounts related to the satisfaction of the associated loan commitment.

The Company's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of the Company's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of the Company's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of the Company's long-term debt (in millions):

			As of March 31, 2026												As of December 31, 2025
			Carrying						Fair						Carrying						Fair
			Value						Value						Value						Value
Long-term debt			$	61,485					$	55,882					$	57,259					$	52,665

(10)    Commitments and Contingencies

Commitments

The Company has the following firm commitments that are not reflected on the Consolidated Balance Sheets.

Construction Commitments

During the three-month period ended March 31, 2026, MidAmerican Energy entered into firm construction commitments totaling $393 million for the remainder of 2026 through 2029 related to the construction of wind-powered, solar-powered and natural gas-powered generating facilities in Iowa.

Guarantees

The Company has entered into guarantees as part of the normal course of business and the sale or transfer of certain assets. These guarantees are not expected to have a material impact on the Company's consolidated financial results.

22

---

Environmental Laws and Regulations

The Company is subject to federal, state, local and foreign laws and regulations regarding air quality, climate change, emissions performance standards, water quality, coal ash disposal, hazardous and other environmental matters that have the potential to impact the Company's current and future operations. The Company believes it is in material compliance with all applicable laws and regulations.

Legal Matters

The Company is party to a variety of legal actions, including litigation, arising out of the normal course of business, some of which assert claims for damages in substantial amounts and are described below. For certain legal actions, parties at times may seek to impose fines, penalties and other costs.

Pursuant to ASC 450, "Contingencies," a provision for a loss contingency is recorded when it is probable a liability is likely to occur and the amount of loss can be reasonably estimated. The Company evaluates the related range of reasonably estimated losses and records a loss based on its best estimate within that range or the lower end of the range if there is no better estimate.

Wildfires

2020 Wildfires and 2022 McKinney Fire

The 2020 Wildfires occurred in September 2020, when a severe weather event with high winds contributed to several major wildfires, resulting in real and personal property and natural resource damage, personal injuries and loss of life and widespread power outages in Oregon and Northern California. The wildfires spread across certain parts of PacifiCorp's service territory and surrounding areas across multiple counties in Oregon and California, burning over 500,000 acres in aggregate and include the Santiam Canyon, Beachie Creek, South Obenchain, Echo Mountain Complex, 242, Archie Creek, Slater and other fires. The Slater fire occurred in both Oregon and California. Third-party reports for these wildfires indicate over 2,000 structures destroyed, including residences; several structures damaged; multiple individuals injured; and several fatalities.

Both the U.S. Department of Agriculture Forest Service ("USFS") and the Oregon Department of Forestry ("ODF") completed investigation reports related to a wildland fire that was first reported outside the Santiam Canyon on August 16, 2020 ("Beachie Creek Fire"), approximately three weeks before the severe weather event described above. The ODF's report concluded that embers from the pre-existing Beachie Creek Fire caused 12 fires within the Santiam Canyon. The ODF's report also found that PacifiCorp's power lines did not contribute to the overall spread of fire into the Santiam Canyon even though PacifiCorp's power lines ignited seven spot fires within the Santiam Canyon that were each suppressed.

The Beachie Creek Fire that spread into the Santiam Canyon burned approximately 193,000 acres; the South Obenchain fire burned approximately 33,000 acres; the Echo Mountain Complex fire burned approximately 3,000 acres; and the 242 fire burned approximately 14,000 acres. The James cases described below are associated with the Beachie Creek (Santiam Canyon), South Obenchain, Echo Mountain Complex and 242 fires, which are four distinct fires located hundreds of miles apart.

The 2022 McKinney Fire occurred on July 29, 2022, when a wildfire began in Siskiyou County, California within PacifiCorp's service territory, burning over 60,000 acres. Third-party reports indicate that the 2022 McKinney Fire resulted in 11 structures damaged; 185 structures destroyed, including residences; 12 injuries; and four fatalities.

Complaints and Demands Associated with the Wildfires

A significant number of complaints and demands alleging similar claims related to the Wildfires have been filed in Oregon and California, including a class action complaint in Oregon associated with 2020 Wildfires (the "James" case)for which certain jury verdicts were issued as described below. The plaintiffs seek damages for economic losses, noneconomic losses, including mental suffering, emotional distress, personal injury and loss of life, punitive damages, other damages and attorneys' fees. Several insurance carriers also filed subrogation complaints in Oregon and California with similar allegations. Additionally, PacifiCorp received correspondence from the U.S. and Oregon Departments of Justice regarding the potential recovery of certain costs and damages alleged to have occurred on federal and state lands in connection with certain of the 2020 Wildfires. As described below, substantially all outstanding complaints and demands are associated with the 2020 Wildfires, specifically the James case and the state of Oregon demands.

23

---

Substantially all amounts sought in outstanding complaints and demands filed in Oregon are associated with the James mass complaints described below, as well as stayed cases for which motions have been filed for consolidation into the James case and the state of Oregon demands. Oregon law provides for doubling of economic and property damages in the event the defendant is found to have acted with gross negligence, recklessness, willfulness or malice. Oregon law provides for trebling of damages associated with timber, shrubs and produce in the event the defendant is determined to have willfully and intentionally trespassed. For class actions, amounts specified by the plaintiffs in the complaints include amounts based on estimates of the potential class size, which ultimately may be significantly greater than estimated.

PacifiCorp has settled various claims associated with the Wildfires, including all wrongful death claims and federal government demands and complaints associated with the Wildfires. For the Archie Creek Fire, Slater Fire and 2022 McKinney Fire, settlements have been reached with substantially all plaintiffs. For the Santiam Canyon, Echo Mountain Complex, South Obenchain and 242 fires, while PacifiCorp settled claims with individual plaintiffs who were granted substitution of counsel in the James case, with the Oregon wineries and with the federal government, claims remain outstanding for a substantial number of plaintiffs associated with the James case. PacifiCorp is also actively cooperating with the Oregon Department of Justice on resolving its alleged claims. Refer below for information regarding the Oregon Court of Appeals opinion issued in April 2026 pertaining to the James class action complaint.

The James Case

On September 30, 2020, a class action complaint against PacifiCorp captioned Jeanyne James et al. v. PacifiCorp, ("James") was filed in Oregon Circuit Court in Multnomah County, Oregon ("Multnomah County Circuit Court Oregon"). The complaint was filed by Oregon residents and businesses who sought to represent a class of all Oregon citizens and entities whose real or personal property was harmed beginning on September 7, 2020, by wildfires in Oregon allegedly caused by PacifiCorp. In November 2021, the plaintiffs filed an amended complaint to limit the class to include Oregon citizens allegedly impacted by the Santiam Canyon, Echo Mountain Complex, South Obenchain and 242 fires, as well as to add claims for noneconomic damages. The amended complaint alleged that PacifiCorp's assets contributed to the Oregon wildfires occurring on or after September 7, 2020, and that PacifiCorp acted with gross negligence, among other things. The amended complaint seeks damages similar to those described above, including not less than $600 million of economic damages and in excess of $1 billion of noneconomic damages for the plaintiffs and the class.

Since the filing of the original class action complaint, several cases have been stayed pending consolidation into James and numerous James class members have been named and damages specified in various complaints. From April 2024 through January 2026, 1,760 James class members filed nine mass damages complaints in Multnomah County Circuit Court Oregon premised on the Phase I liability verdict, as described below, each referencing the original James case as the lead case. The James mass complaints make damages-only allegations seeking for each individual class member $5 million of economic damages, $25 million of noneconomic damages and punitive damages equal to 0.25 times the amount of economic and noneconomic damages, as well as doubling of economic damages. Complaints for some of the plaintiffs in the mass complaints have been dismissed, amended or re-filed.

The Multnomah County Circuit Court Oregon determined that the James case would be divided into a liability phase ("Phase I") and a damages phase ("Phase II"). In June 2023, a jury in the Phase I liability trial found PacifiCorp's conduct grossly negligent, reckless and willful as to each of the 17 named plaintiffs and the entire class. The jury awarded economic and noneconomic damages, as well as punitive damages. After the jury verdict, the Multnomah County Circuit Court Oregon doubled the Phase I plaintiffs' economic damages, in accordance with Oregon law, and added punitive damages by applying a 0.25 multiplier to the awarded economic and noneconomic damages. The Multnomah County Circuit Court Oregon granted PacifiCorp's subsequent motion to offset the damage awards by deducting insurance proceeds received by any of the plaintiffs.

PacifiCorp subsequently appealed the Phase I liability verdict, and on April 8, 2026, the verdict was reversed and remanded by the Oregon Court of Appeals, as described in more detail below.

24

---

While PacifiCorp's appeal of the Phase I verdict was pending, the Multnomah County Circuit Court Oregon held numerous Phase II trials, in which a series of juries awarded damages to groups of James class members. The majority of these trials were scheduled pursuant to a case management order called "CMO No. 11." PacifiCorp has filed notices of appeal for the subsequent jury verdicts in the Phase II trials once limited judgments are entered and any post-trial motions filed. The James jury verdicts to date have awarded total net damages of $1,252 million to 201 plaintiffs, including $133 million of doubled economic damages, $910 million of noneconomic damages, $244 million of punitive damages and partially offset by estimated insurance offsets of $35 million. To date, PacifiCorp has been required to bond the amounts awarded by the James limited judgments in order to stay payment of damages while on appeal. As of the date of this filing, PacifiCorp has posted bonds totaling $719 million associated with the limited judgments entered to date for 129 plaintiffs. Based on the April 2026 Oregon Court of Appeals opinion, the existing bonds could eventually be discharged and any future bonding requirements eliminated.

The Oregon Court of Appeals' April 2026 opinion reversing the Phase I verdict explained that the Multnomah County Circuit Court Oregon erred in instructing the jury that they could "assume that the evidence at the trial applies to all class members." The Oregon Court of Appeals further concluded that the erroneous jury instruction "was prejudicial to PacifiCorp" because it "gave rise to some likelihood that the jury reached an erroneous result." Because the Oregon Court of Appeals reversed and remanded on the instructional error issue presented in PacifiCorp's appellate brief, it did not address the majority of PacifiCorp's other appealed issues. However, the Oregon Court of Appeals emphasized that the Multnomah County Circuit Court Oregon has the authority on remand to reconsider its class certification decision and reconsider whether a single class is appropriate in this case. The Oregon Court of Appeals determined PacifiCorp was the prevailing party and awarded costs to PacifiCorp. Either party can file a petition for review with the Oregon Supreme Court within 35 days of the Oregon Court of Appeals opinion, subject to extension. Whether the Oregon Supreme Court accepts a request for review is at its discretion.

On April 9, 2026, the Multnomah County Circuit Court Oregon ordered a stay of scheduled James Phase II trials (except for a trial that began April 6, 2026, and subsequently concluded on April 13, 2026) and mandatory mediation. The Multnomah County Circuit Court Oregon asked the parties to submit briefing on the merits, scope and duration of the stay in advance of a May 22, 2026, hearing.

Estimated Losses for and Settlements Associated with the Wildfires

Based on the facts and circumstances available to PacifiCorp as of the date of this filing, including (i) cause and origin investigations; (ii) ongoing settlement and mediation activities; (iii) other litigation matters and upcoming legal proceedings; and (iv) the status of the James case, PacifiCorp recorded cumulative estimated probable losses associated with the Wildfires of $2,853 million through March 31, 2026. PacifiCorp's cumulative accrual includes estimates of probable losses for fire suppression costs, real and personal property damages, natural resource damages and noneconomic damages such as personal injury damages and loss of life damages that it is reasonably able to estimate at this time and which is subject to change as additional relevant information becomes available.

Through March 31, 2026, PacifiCorp paid $2,276 million in settlements associated with the Wildfires. As a result of the settlements, various trials have been cancelled. In April 2026, PacifiCorp made additional settlement payments related to the Wildfires totaling $4 million.

The following table presents changes in PacifiCorp's liability for estimated losses associated with the Wildfires (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Beginning balance															$	1,161					$	1,536
Payments															(584)						(114)
Ending balance															$	577					$	1,422

As of March 31, 2026 and December 31, 2025, $160 million and $734 million of PacifiCorp's liability for estimated losses associated with the Wildfires was included in other current liabilities on the Consolidated Balance Sheets. The amounts reflected as current as of March 31, 2026, reflect amounts reasonably expected to be paid out within the next year based on settlements reached as well as ongoing settlement and mediation efforts. The remainder of PacifiCorp's liability for estimated losses associated with the Wildfires as of March 31, 2026 and December 31, 2025, was included in other long-term liabilities on the Consolidated Balance Sheets.

25

---

As of March 31, 2025, PacifiCorp had received all expected insurance recoveries with the final $98 million of proceeds received during the three-month period ended March 31, 2025. No additional insurance recoveries beyond those received to date are expected to be available.

It is reasonably possible PacifiCorp will incur material additional losses beyond the amounts accrued for the Wildfires that could have a material adverse effect on PacifiCorp's financial condition. PacifiCorp is currently unable to reasonably estimate a specific range of possible additional losses that could be incurred due to the number of properties and parties involved, including claimants in the class to the James case, the variation in the types of properties and damages and the ultimate outcome of legal actions, including mediation, settlement negotiations, jury verdicts and the James appeals process, including the April 2026 Oregon Court of Appeals opinion.

HomeServices Antitrust Cases

HomeServices is currently defending against several antitrust cases, all in federal district courts. In each case, plaintiffs claim HomeServices and certain of its subsidiaries (in one instance, HomeServices and BHE) conspired with co-defendants to artificially inflate real estate commissions by following and enforcing multiple listing service ("MLS") rules that require listing agents to offer a commission split to cooperating agents in order for the property to appear on the MLS ("Cooperative Compensation Rule"). None of the complaints specify damages sought. However, two cases allege Texas state law deceptive trade practices claims, for which plaintiffs have asserted damages totaling approximately $9 billion by separate written notice as required by Texas law.

In April 2019, the Burnett (formerly Sitzer) et al. v. HomeServices of America, Inc. et al. complaint was filed in the U.S. District Court for the Western District of Missouri (the "Burnett case"). This lawsuit, which was certified as a class in April 2022, was originally brought on behalf of named plaintiffs Joshua Sitzer and Amy Winger against the National Association of Realtors ("NAR"), Anywhere Real Estate, HomeServices, RE/MAX, LLC, and Keller Williams Realty, Inc. HSF Affiliates LLC and BHH Affiliates, LLC, each a subsidiary of HomeServices, were subsequently added as defendants. Rhonda Burnett became a lead class plaintiff in June 2021. The jury trial commenced on October 16, 2023, and the jury returned a verdict for the plaintiffs on October 31, 2023, finding that the named defendants participated in a conspiracy to follow and enforce the Cooperative Compensation Rule, which conspiracy had the purpose or effect of raising, inflating, or stabilizing broker commission rates paid by home sellers. The jury further found that the class plaintiffs had proved damages in the amount of $1.8 billion. Joint and several liability applies for the co-defendants. Federal law authorizes trebling of damages and the award of pre-judgment interest and attorney fees. Prior to the trial, Anywhere Real Estate and RE/MAX, LLC reached settlement agreements with the plaintiffs and settlements were reached by Keller Williams, NAR and HomeServices subsequent to the trial. All settlements received court approval, had final judgments entered by the court and were appealed to the U.S. Court of Appeals for the Eighth Circuit. All appeals were fully briefed by December 19, 2025, and oral arguments took place on January 14, 2026. A ruling from the court on the appeals is pending.

The final HomeServices settlement agreement with the plaintiffs reached on April 25, 2024, settles all claims asserted against HomeServices, HSF Affiliates LLC and BHH Affiliates, LLC in the Burnett case and effectuates a nationwide class settlement. The final settlement agreement includes scheduled payments over four years aggregating $250 million. HomeServices has made payments of $10 million in September 2024, $57 million in February 2025 and $63 million in February 2026. HomeServices recognized an after-tax charge of approximately $140 million in the first quarter of 2024, and the liability outstanding as of March 31, 2026, and December 31, 2025, was $100 million and $158 million, respectively. If the settlement is not affirmed by the U.S. Court of Appeals for the Eighth Circuit, HomeServices intends to vigorously appeal on multiple grounds the jury's findings and damage award in the Burnett case, including whether the case can proceed as a class action. The appeals process and further actions could take several years.

26

---

(11)    Revenue from Contracts with Customers

Energy Products and Services

The following table summarizes the Company's energy products and services revenue from contracts with customers ("Customer Revenue") by regulated and nonregulated, with further disaggregation of regulated by line of business, including a reconciliation to the Company's reportable segment information included in Note 13 (in millions):

			For the Three-Month Period Ended March 31, 2026
			PacifiCorp						MidAmerican Funding						NV Energy						Northern Powergrid						BHE Pipeline Group						BHE Transmission						BHE Renewables						BHE and Other(1)						Total
Customer Revenue:
Regulated:
Retail electric			$	1,686					$	589					$	694					$	—					$	—					$	—					$	—					$	(1)					$	2,968
Retail gas			—						332						37						—						—						—						—						—						369
Wholesale			21						186						15						—						2						—						—						(1)						223
Transmission and distribution			35						13						16						288						—						164						—						—						516
Interstate pipeline			—						—						—						—						993						—						—						(57)						936
Other			42						—						—						—						3						—						—						1						46
Total Regulated			1,784						1,120						762						288						998						164						—						(58)						5,058
Nonregulated			—						3						4						18						383						23						188						(1)						618
Total Customer Revenue			1,784						1,123						766						306						1,381						187						188						(59)						5,676
Other revenue			24						17						—						30						4						2						57						—						134
Total			$	1,808					$	1,140					$	766					$	336					$	1,385					$	189					$	245					$	(59)					$	5,810

			For the Three-Month Period Ended March 31, 2025
			PacifiCorp						MidAmerican Funding						NV Energy						Northern Powergrid						BHE Pipeline Group						BHE Transmission						BHE Renewables						BHE and Other(1)						Total
Customer Revenue:
Regulated:
Retail electric			$	1,647					$	545					$	633					$	—					$	—					$	—					$	—					$	(1)					$	2,824
Retail gas			—						309						49						—						—						—						—						—						358
Wholesale			13						116						16						—						1						—						—						—						146
Transmission and distribution			48						14						17						372						—						155						—						—						606
Interstate pipeline			—						—						—						—						859						—						—						(46)						813
Other			27						—						—						—						—						—						—						—						27
Total Regulated			1,735						984						715						372						860						155						—						(47)						4,774
Nonregulated			—						2						2						25						315						29						211						—						584
Total Customer Revenue			1,735						986						717						397						1,175						184						211						(47)						5,358
Other revenue			33						28						1						29						10						1						46						—						148
Total			$	1,768					$	1,014					$	718					$	426					$	1,185					$	185					$	257					$	(47)					$	5,506

(1)The BHE and Other reportable segment represents amounts related principally to other corporate entities, corporate functions and intersegment eliminations.

27

---

Real Estate Services

The following table summarizes the Company's real estate services Customer Revenue by line of business (in millions):

															HomeServices
									Three-Month Periods
									Ended March 31,
															2026						2025
Customer Revenue:
Brokerage															$	778					$	781
Franchise															13						10
Total Customer Revenue															791						791
Mortgage and other revenue															71						69
Total															$	862					$	860

Remaining Performance Obligations

The following table summarizes the Company's revenue it expects to recognize in future periods related to significant unsatisfied remaining performance obligations for fixed contracts with expected durations in excess of one year as of March 31, 2026, by reportable segment (in millions):

			Performance obligations expected to be satisfied:
			Less than 12 months						More than 12 months						Total
BHE Pipeline Group			$	3,413					$	18,810					$	22,223

(12)    Components of Accumulated Other Comprehensive Loss, Net

The following table shows the change in accumulated other comprehensive loss by each component of other comprehensive income (loss), net of applicable income tax (in millions):

			Unrecognized						Foreign						Unrealized												AOCI
			Amounts On						Currency						Gains												Attributable
			Retirement						Translation						on Cash						Noncontrolling						To BHE
			Benefits						Adjustment						Flow Hedges						Interests						Shareholders, Net
Balance, December 31, 2024			$	(421)					$	(1,999)					$	78					$	1					$	(2,341)
Other comprehensive income (loss)			—						169						(6)						—						163
Balance, March 31, 2025			$	(421)					$	(1,830)					$	72					$	1					$	(2,178)
Balance, December 31, 2025			$	(482)					$	(1,409)					$	46					$	1					$	(1,844)
Other comprehensive income (loss)			17						(143)						(6)						—						(132)
Balance, March 31, 2026			$	(465)					$	(1,552)					$	40					$	1					$	(1,976)

28

---

(13)    Segment Information

The Company's chief operating decision maker ("CODM") is its President and Chief Executive Officer. Earnings on common shares for each reportable segment are considered by the CODM in allocating resources and capital. The CODM generally considers actual results versus historical results, budgets or forecasts, as well as unique risks and opportunities, when making decisions about the allocation of resources and capital to each reportable segment. The Company's reportable segments with foreign operations include Northern Powergrid, whose business is principally in the United Kingdom, and BHE Transmission, whose business includes operations in Canada. Intersegment eliminations and adjustments, including the allocation of goodwill, have been made. Information related to the Company's reportable segments is shown below (in millions):

						For the Three-Month Period Ended March 31, 2026
						PacifiCorp						MidAmerican Funding						NV Energy						Northern Powergrid						BHE Pipeline Group						BHE Transmission						BHE Renewables(2)						HomeServices						BHE and Other(1)						Total
Operating revenue						$	1,808					$	1,140					$	766					$	336					$	1,385					$	189					$	245					$	862					$	(59)					$	6,672
Cost of sales						755						484						371						27						51						5						35						605						(58)						2,275
Operations and maintenance						463						220						160						69						233						39						97						263						17						1,561
Depreciation and amortization						310						277						148						98						165						52						76						9						—						1,135
Interest expense						227						109						85						48						73						37						31						—						136						746
Interest and dividend income						27						6						8						1						11						—						2						4						(5)						54
Income tax expense (benefit)						(21)						(218)						4						15						182						4						(319)						(4)						(73)						(430)
Equity income (loss)						—						—						1						—						28						22						(185)						—						—						(134)
Other segment items						(30)						(29)						36						(17)						(114)						(10)						(14)						(5)						(8)						(191)
Earnings on common shares						$	71					$	245					$	43					$	63					$	606					$	64					$	128					$	(12)					$	(94)					$	1,114
Capital expenditures						$	717					$	418					$	631					$	171					$	215					$	108					$	169					$	3					$	(14)					$	2,418

29

---

						For the Three-Month Period Ended March 31, 2025
						PacifiCorp						MidAmerican Funding						NV Energy						Northern Powergrid						BHE Pipeline Group						BHE Transmission						BHE Renewables(2)						HomeServices						BHE and Other(1)						Total
Operating revenue						$	1,768					$	1,014					$	718					$	426					$	1,185					$	186					$	257					$	860					$	(48)					$	6,366
Cost of sales						718						369						357						29						54						6						45						605						(47)						2,136
Operations and maintenance						424						227						137						55						224						35						134						254						13						1,503
Depreciation and amortization						299						307						138						87						152						55						68						10						—						1,116
Interest expense						187						105						79						33						70						36						31						1						144						686
Interest and dividend income						28						6						6						3						23						—						4						4						(12)						62
Income tax expense (benefit)						(19)						(236)						3						57						144						4						(336)						(6)						(10)						(399)
Equity income (loss)						—						—						1						—						27						23						(172)						1						—						(120)
Other segment items						(9)						(20)						11						(23)						(103)						(11)						(7)						(16)						96						(82)
Earnings on common shares						$	178					$	228					$	22					$	145					$	488					$	62					$	140					$	(15)					$	(64)					$	1,184
Capital expenditures						$	688					$	405					$	456					$	157					$	188					$	81					$	112					$	1					$	40					$	2,128

(1)The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other, relate principally to other corporate entities, corporate functions and intersegment eliminations.

(2)Income tax expense (benefit) includes the tax attributes of disregarded entities that are not required to pay income taxes and the earnings of which are taxable directly to BHE.

The following table summarizes the other segment items category by the Company's reportable segments:

PacifiCorp

MidAmerican Funding

NV Energy

Northern Powergrid

BHE Pipeline Group

BHE Transmission

BHE Renewables

HomeServices

Property and other taxes

X

X

X

X

X

X

X

X

Capitalized interest

X

X

X

X

X

X

Allowance for equity funds

X

X

X

X

X

Gains (losses) on marketable securities, net

X

X

X

X

X

X

X

Other income (expense), net

X

X

X

X

X

X

X

X

Net income attributable to noncontrolling interests

X

X

X

X

X

30

---

The following table summarizes the Company's total assets by reportable segment (in millions):

			As of
			March 31,						December 31,
			2026						2025
Assets:
PacifiCorp			$	40,776					$	38,323
MidAmerican Funding			29,877						29,712
NV Energy			22,336						21,118
Northern Powergrid			10,630						10,819
BHE Pipeline Group			23,172						22,977
BHE Transmission			9,683						9,762
BHE Renewables			11,711						11,644
HomeServices			3,422						3,449
BHE and Other(1)			422						523
Total assets			$	152,029					$	148,327

(1)The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other, relate principally to other corporate entities, corporate functions and intersegment eliminations.

The following table shows the change in the carrying amount of goodwill by reportable segment for the three-month period ended March 31, 2026 (in millions):

			PacifiCorp						MidAmerican Funding						NV Energy						Northern Powergrid						BHE Pipeline Group						BHE Transmission						BHE Renewables						HomeServices												Total
December 31, 2025			$	1,129					$	2,102					$	2,369					$	990					$	1,814					$	1,439					$	95					$	1,583											$	11,521
Foreign currency translation			—						—						—						(13)						—						(19)						—						—												(32)
Dispositions			(89)						—						—						—						—						—						—						—												(89)
March 31, 2026			$	1,040					$	2,102					$	2,369					$	977					$	1,814					$	1,420					$	95					$	1,583											$	11,400

31

---

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

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of the Company during the periods included herein. Explanations include management's best estimate of the impact of weather, customer growth, usage trends and other factors. This discussion should be read in conjunction with the Company's historical unaudited Consolidated Financial Statements and Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q. The Company's actual results in the future could differ significantly from the historical results.

BHE, a wholly owned subsidiary of Berkshire Hathaway, is a holding company headquartered in Iowa that has investments in a highly diversified portfolio of locally managed and operated businesses principally engaged in the energy industry. The Company's operations are organized as eight business segments: PacifiCorp, MidAmerican Funding (which primarily consists of MidAmerican Energy), NV Energy (which primarily consists of Nevada Power and Sierra Pacific), Northern Powergrid (which primarily consists of Northern Powergrid (Northeast) plc and Northern Powergrid (Yorkshire) plc), BHE Pipeline Group (which primarily consists of BHE GT&S, Northern Natural Gas and Kern River), BHE Transmission (which consists of BHE Canada (which primarily consists of AltaLink) and BHE U.S. Transmission), BHE Renewables and HomeServices. BHE, through these locally managed and operated businesses, has investments in four utility companies in the U.S. serving customers in 11 states, two electricity distribution companies in Great Britain, five interstate natural gas pipeline companies and interests in an LNG export, import and storage facility in the U.S., an electric transmission business in Canada, interests in electric transmission businesses in the U.S., a renewable energy business primarily investing in wind, solar, geothermal and hydroelectric projects, one of the largest residential real estate brokerage firms in the U.S. and a residential real estate brokerage franchise business in the U.S. The reportable segment financial information includes all necessary adjustments and eliminations needed to conform to the Company's significant accounting policies. The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other, relate principally to other corporate entities, corporate functions and intersegment eliminations.

32

---

Results of Operations for the First Quarter of 2026 and 2025

Overview

Operating revenue and earnings on common shares for the Company's reportable segments are summarized as follows (in millions):

			First Quarter
			2026						2025						Change
Operating revenue:
PacifiCorp			$	1,808					$	1,768					$	40					2		%
MidAmerican Funding			1,140						1,014						126						12
NV Energy			766						718						48						7
Northern Powergrid			336						426						(90)						(21)
BHE Pipeline Group			1,385						1,185						200						17
BHE Transmission			189						186						3						2
BHE Renewables			245						257						(12)						(5)
HomeServices			862						860						2						—
BHE and Other			(59)						(48)						(11)						(23)
Total operating revenue			$	6,672					$	6,366					$	306					5		%
Earnings on common shares:
PacifiCorp			$	71					$	178					$	(107)					(60)		%
MidAmerican Funding			245						228						17						7
NV Energy			43						22						21						95
Northern Powergrid			63						145						(82)						(57)
BHE Pipeline Group			606						488						118						24
BHE Transmission			64						62						2						3
BHE Renewables(1)			128						140						(12)						(9)
HomeServices			(12)						(15)						3						20
BHE and Other			(94)						(64)						(30)						(47)
Total earnings on common shares			$	1,114					$	1,184					$	(70)					(6)		%

(1)Includes the tax attributes of disregarded entities that are not required to pay income taxes and the earnings of which are taxable directly to BHE.

Earnings on common shares decreased $70 million for the first quarter of 2026 compared to 2025. Included in these results was a pre-tax gain in the first quarter of 2025 of $110 million ($87 million after-tax) related to the Company's investment in BYD Company Limited. Excluding the impact of this item, earnings on common shares for the first quarter of 2026 increased $17 million, or 2%, compared to adjusted earnings on common shares for the first quarter of 2025 of $1,097 million.

33

---

The decrease in earnings on common shares for the first quarter of 2026 compared to 2025 was primarily due to the following:

•The Utilities' earnings decreased $69 million, primarily due to higher operations and maintenance expense, increased interest expense and lower PTCs recognized, partially offset by higher electric utility margin and increased allowances for equity and borrowed funds used during construction. Electric retail customer volumes increased 1.7% for the first quarter of 2026 compared to 2025, primarily due to an increase in the average number of customers and higher customer usage, partially offset by the unfavorable impact of weather;

•Northern Powergrid's earnings decreased $82 million, primarily due to lower distribution revenue and higher interest expense, partially offset by lower income tax expense from a charge related to the March 2025 enactment of a change in the Energy Profits Levy income tax;

•BHE Pipeline Group's earnings increased $118 million, primarily due to higher transportation revenues at Northern Natural Gas and higher variable revenue at Cove Point;

•BHE Renewables' earnings decreased $12 million, primarily due to lower earnings on owned wind projects and from the wind tax equity investment portfolio, partially offset by higher geothermal and natural gas earnings;

•BHE and Other's earnings decreased $30 million, primarily due to the $87 million after-tax gain recognized in 2025 related to the Company's investment in BYD Company Limited, partially offset by higher federal income tax credits recognized on a consolidated basis and lower interest expense.

Reportable Segment Results

PacifiCorp

Operating revenue increased $40 million for the first quarter of 2026 compared to 2025, primarily due to higher retail revenue of $44 million. Retail revenue increased primarily due to price impacts of $75 million from higher average rates, largely from tariff changes and product mix, partially offset by $31 million from lower retail volumes. Retail customer volumes decreased 1.2% primarily due to the unfavorable impact of weather and lower customer usage, partially offset by an increase in the average number of customers.

Earnings decreased $107 million for the first quarter of 2026 compared to 2025, primarily due to increased interest expense of $40 million, higher operations and maintenance expense of $39 million, lower PTCs recognized of $17 million and higher depreciation and amortization expense of $11 million, partially offset by higher utility margin of $3 million. Operations and maintenance expense increased due to higher vegetation management and other wildfire prevention costs, lower federal grant reimbursements, higher general plant and maintenance costs and higher legal fees. Interest expense increased mainly due to higher average outstanding long-term debt balances. Depreciation and amortization increased largely due to additional assets placed in-service. Utility margin increased primarily due higher retail rates and lower thermal generation costs, partially offset by unfavorable deferred net power costs, lower retail volumes and higher purchased electricity costs.

MidAmerican Funding

Operating revenue increased $126 million for the first quarter of 2026 compared to 2025, primarily due to higher electric operating revenue of $80 million and higher natural gas operating revenue of $45 million. Electric operating revenue increased due to higher retail revenue of $43 million and higher wholesale and other revenue of $37 million. Electric retail revenue increased primarily due to higher recoveries through adjustment clauses of $27 million (fully offset in cost of sales, operations and maintenance expense and income tax benefit), higher retail volumes of $12 million and price impacts of $4 million from changes in sales mix. Electric retail customer volumes increased 4.4%, primarily due to higher customer usage, partially offset by the unfavorable impact of weather. Electric wholesale and other revenue increased mainly due to higher average wholesale prices of $41 million. Natural gas operating revenue increased primarily due to higher energy-related rates of $45 million (fully offset in cost of sales) from a higher average per-unit cost of natural gas sold.

Earnings increased $17 million for the first quarter of 2026 compared to 2025, primarily due to lower depreciation and amortization expense of $30 million, higher electric utility margin of $10 million and lower operations and maintenance expense of $7 million, partially offset by lower PTCs recognized of $17 million and higher interest expense of $4 million. Depreciation and amortization expense decreased primarily due to the impacts of certain regulatory mechanisms, partially offset by additional assets placed in-service. Electric utility margin increased primarily due to higher retail and wholesale revenues and lower thermal generation costs, partially offset by higher purchased electricity costs. Operations and maintenance expense decreased mainly due to lower electric distribution costs. Interest expense increased largely due to higher average outstanding long-term debt balances.

34

---

NV Energy

Operating revenue increased $48 million for the first quarter of 2026 compared to 2025, primarily due to higher electric operating revenue of $59 million, partially offset by lower natural gas operating revenue of $12 million, largely due to lower energy-related rates (fully offset in cost of sales) from a lower average per-unit cost of natural gas sold. Electric operating revenue increased primarily due to higher fully bundled energy rates (fully offset in cost of sales) of $25 million, increased base rates of $18 million at Nevada Power and higher customer volumes of $7 million. Electric retail customer volumes increased 4.3%, primarily due to an increase in the average number of customers and the favorable impact of weather.

Earnings increased $21 million for the first quarter of 2026 compared to 2025, primarily due to higher electric utility margin of $34 million and increased allowances for borrowed and equity funds used during construction of $24 million, partially offset by higher operations and maintenance expense of $23 million, increased depreciation and amortization of $10 million and higher interest expense of $6 million. Electric utility margin increased primarily due to higher base rates at Nevada Power and higher retail volumes. Operations and maintenance expense increased primarily due to higher administrative and technology costs and increased insurance premiums. Interest expense increased mainly due to higher average outstanding long-term debt balances.

Northern Powergrid

Operating revenue decreased $90 million for the first quarter of 2026 compared to 2025, primarily due to lower distribution revenue of $105 million, partially offset by $21 million from the weaker U.S. dollar. Distribution revenue decreased primarily due to lower tariff rates driven by the impacts of inflation.

Earnings decreased $82 million for the first quarter of 2026 compared to 2025, primarily due to lower distribution revenue and higher interest expense, partially offset by lower income tax expense from a charge related to the March 2025 enactment of a change in the Energy Profits Levy income tax of $14 million. Interest expense increased mainly due to higher average outstanding long-term debt balances.

BHE Pipeline Group

Operating revenue increased $200 million for the first quarter of 2026 compared to 2025, primarily due to higher operating revenue of $115 million at Northern Natural Gas and higher operating revenue of $76 million at BHE GT&S. The increase in operating revenue at Northern Natural Gas was primarily due to the impacts of a general rate case, with interim rates effective January 1, 2026, subject to refund, of $70 million and higher transportation revenue in the Field Area of $35 million, largely from higher rates. The increase in operating revenue at BHE GT&S was primarily due to favorable variable revenue at Cove Point of $59 million due to higher volumes and higher prices from extremely cold weather in the first quarter of 2026.

Earnings increased $118 million for the first quarter of 2026 compared to 2025, primarily due to higher earnings of $80 million at Northern Natural Gas and higher earnings of $36 million at BHE GT&S. The increase at Northern Natural Gas was primarily due to higher transportation revenues and higher margin on gas sales of $11 million from system balancing activities, partially offset by higher depreciation and amortization expense of $6 million from additional assets placed in-service. The increase at BHE GT&S was primarily due to favorable variable revenue at Cove Point and a gain from the initial conveyance of development rights related to a natural gas storage field at EGTS of $16 million, partially offset by decreased interest and dividend income of $10 million and higher operations and maintenance expense of $12 million, largely due to increased employee costs and higher plant operations and maintenance costs.

BHE Transmission

Operating revenue increased $3 million for the first quarter of 2026 compared to 2025, primarily due to $8 million from the weaker U.S. dollar, partially offset by $4 million of lower revenue from non-regulated wind-powered generating facilities from lower pricing.

Earnings increased $2 million for the first quarter of 2026 compared to 2025, primarily due to the weaker U.S. dollar.

35

---

BHE Renewables

Operating revenue decreased $12 million for the first quarter of 2026 compared to 2025, primarily due to lower electric and natural gas retail energy services revenue of $24 million from the wind down of the retail energy services business which was exited in December 2024 and lower wind revenue of $19 million, partially offset by higher natural gas and geothermal revenue of $32 million from higher natural gas pricing and higher geothermal generation. Wind revenue decreased due to lower generation and unfavorable changes in the valuations of certain derivative contracts.

Earnings decreased $12 million for the first quarter of 2026 compared to 2025, primarily due to lower wind earnings of $43 million, partially offset by higher geothermal and natural gas earnings of $35 million. Wind earnings decreased due to lower earnings from owned wind projects of $22 million, mainly from lower revenue and lower PTCs recognized of $3 million, and lower earnings from the wind tax equity investment portfolio of $21 million, largely due to timing of equity earnings and lower PTCs recognized of $12 million. Geothermal and natural gas earnings increased mainly due to lower maintenance costs, higher natural gas pricing and increased geothermal generation.

HomeServices

Operating revenue increased $2 million for the first quarter of 2026 compared to 2025, primarily due to higher mortgage, franchise and other revenue of $9 million, partially offset by lower brokerage and settlement services revenue of $7 million. The decrease in brokerage and settlement services revenue resulted from a 6% decrease in closed brokerage units driven by the continued slowdown of overall market activity due to increased interest rates and low inventory.

Earnings increased $3 million for the first quarter of 2026 compared to 2025, primarily due to a title company divestiture loss recognized in 2025, partially offset by unfavorable operating expenses.

BHE and Other

Earnings decreased $30 million for the first quarter of 2026 compared to 2025, primarily due to the $87 million after-tax gain recognized in 2025 related to the Company's investment in BYD Company Limited, partially offset by $48 million of higher federal income tax credits recognized on a consolidated basis and lower interest expense of $9 million largely due to lower average outstanding long-term debt balances.

Liquidity and Capital Resources

Each of BHE's direct and indirect subsidiaries is organized as a legal entity separate and apart from BHE and its other subsidiaries. It should not be assumed that the assets of any subsidiary will be available to satisfy BHE's obligations or the obligations of its other subsidiaries. However, unrestricted cash or other assets that are available for distribution may, subject to applicable law, regulatory commitments and the terms of financing and ring-fencing arrangements for such parties, be advanced, loaned, paid as dividends or otherwise distributed or contributed to BHE or affiliates thereof. The Company's long-term debt may include provisions that allow BHE or its subsidiaries to redeem such debt in whole or in part at any time. These provisions generally include make-whole premiums. Refer to Note 18 of Notes to Consolidated Financial Statements in Item 8 of the Company's Annual Report on Form 10-K for the year ended December 31, 2025, for further discussion regarding the limitation of distributions from BHE's subsidiaries.

36

---

As of March 31, 2026, the Company's total net liquidity was as follows (in millions):

																																													BHE Pipeline
															MidAmerican						NV						Northern						BHE												Group and
			BHE						PacifiCorp						Funding						Energy						Powergrid						Canada						HomeServices						Other						Total
Cash and cash equivalents			$	148					$	2,177					$	529					$	666					$	20					$	94					$	251					$	318					$	4,203
Credit facilities(1)			3,500						2,900						1,509						1,000						359						665						1,525						—						11,458
Less:
Short-term debt			(85)						—						—						—						(157)						(65)						(698)						—						(1,005)
Tax-exempt bond support and letters of credit			—						—						(258)						—						—						(4)						—						—						(262)
Net credit facilities			3,415						2,900						1,251						1,000						202						596						827						—						10,191
Total net liquidity			$	3,563					$	5,077					$	1,780					$	1,666					$	222					$	690					$	1,078					$	318					$	14,394
Credit facilities:
Maturity dates			2028						2026, 2028						2026, 2028						2028						2026, 2028						2028, 2029, 2030						2026, 2027, 2030

(1)Includes $94 million drawn on capital expenditure and other uncommitted credit facilities at Northern Powergrid.

Operating Activities

Net cash flows from operating activities for the three-month periods ended March 31, 2026 and 2025, were $1.4 billion and $2.0 billion, respectively. The decrease was primarily due to higher wildfire liability settlement payments, changes in working capital and higher cash paid for interest, partially offset by favorable operating results and higher income tax receipts.

The timing of the Company's income tax cash flows from period to period can be significantly affected by the estimated federal income tax payment methods selected and assumptions made for each payment date.

Investing Activities

Net cash flows from investing activities for the three-month periods ended March 31, 2026 and 2025, were $(2.4) billion and $(1.6) billion, respectively. The change was primarily due to lower proceeds from sales of BYD Company Limited common stock of $525 million and higher capital expenditures of $290 million. Refer to "Future Uses of Cash" for a discussion of capital expenditures.

Financing Activities

Net cash flows from financing activities for the three-month period ended March 31, 2026, was $3,493 million. Sources of cash totaled $4.8 billion and consisted mainly of proceeds from subsidiary debt issuances of $4.6 billion. Uses of cash totaled $1.3 billion and consisted mainly of repayments of net repayments of short-term debt of $989 million, repayments of subsidiary debt of $210 million and distributions to noncontrolling interests of $68 million.

For a discussion of recent financing transactions, refer to Notes 6 of Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q.

Net cash flows from financing activities for the three-month period ended March 31, 2025, was $0.9 billion. Sources of cash totaled $2.4 billion and consisted of proceeds from subsidiary debt issuances. Uses of cash totaled $1.4 billion and consisted mainly of preferred stock redemptions of $481 million, net repayments of short-term debt of $441 million and repayments of BHE senior debt of $400 million.

37

---

Letters of Credit

In April 2026, PacifiCorp entered into a letter of credit agreement under which letters of credit will be made available solely to provide collateral support for surety bonds issued pursuant to a corresponding surety arrangement for supersedeas undertakings to secure the performance and stay enforcement of trial court judgments entered against PacifiCorp relating to the James case. Refer to Note 6 of Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q for additional information regarding this arrangement.

Future Uses of Cash

The Company has available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, the issuance of commercial paper, the use of unsecured revolving credit facilities, the issuance of equity and other sources. These sources are expected to provide funds required for current operations, capital expenditures, acquisitions, investments, debt retirements and other capital requirements. The availability and terms under which BHE and each subsidiary has access to external financing depends on a variety of factors, including regulatory approvals, its credit ratings, investors' judgment of risk and conditions in the overall capital markets, including the condition of the utility industry and project finance markets, among other items.

Capital Expenditures

Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, impacts to customer rates; changes in environmental and other rules and regulations; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; load projections; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital.

38

---

The Company's historical and forecast capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items, are as follows (in millions):

			Three-Month Periods												Annual
			Ended March 31,												Forecast
			2025						2026						2026
Capital expenditures by business:
PacifiCorp			$	688					$	717					$	2,791
MidAmerican Funding			405						418						2,570
NV Energy			456						631						3,200
Northern Powergrid			157						171						863
BHE Pipeline Group			188						215						1,510
BHE Transmission			81						108						422
BHE Renewables			112						169						484
HomeServices			1						3						34
BHE and Other(1)			40						(14)						(2)
Total			$	2,128					$	2,418					$	11,872

Capital expenditures by type:
Electric distribution			$	554					$	543					$	2,782
Electric transmission			372						446						2,728
Natural gas transmission and storage			100						175						1,254
Wind generation			99						70						1,027
Solar generation			75						134						788
Wildfire prevention			179						151						624
Electric battery storage			31						8						63
Other			718						891						2,606
Total			$	2,128					$	2,418					$	11,872

(1)BHE and Other represents amounts related principally to other entities corporate functions and intersegment eliminations.

The Company's historical and forecast capital expenditures consisted mainly of the following:

•Electric distribution includes both growth and operating expenditures. Growth expenditures include spending for new customer connections and enhancements to existing customer connections. Operating expenditures include spending for ongoing distribution systems infrastructure enhancements at the Utilities and Northern Powergrid, storm damage restoration and repairs and investments in routine expenditures for distribution needed to serve existing and expected demand.

•Electric transmission includes both growth and operating expenditures. Operating expenditures include spending for system reinforcement, upgrades and replacements of facilities to maintain system reliability and investments in routine expenditures for transmission needed to serve existing and expected demand. Growth expenditures include spending for the following:

◦PacifiCorp's transmission investment primarily reflects costs associated with major transmission projects totaling $85 million and $49 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for major transmission projects that are expected to be placed in‑service through 2032 totals $335 million for the remainder of 2026.

◦Nevada Utilities' Greenlink Nevada transmission expansion program. Expenditures for the expansion program and other growth projects totaled $182 million and $121 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for the expansion program estimated to be placed in-service in 2027 through 2028 and other growth projects totals $979 million for the remainder of 2026.

39

---

•Natural gas transmission and storage includes both growth and operating expenditures. Growth expenditures include, among other items, spending for customer driven expansion projects. Operating expenditures include spending for pipeline integrity projects, automation and controls upgrades, corrosion control, unit exchanges, compressor modifications, projects related to Pipeline and Hazardous Materials Safety Administration natural gas storage rules and natural gas transmission, storage, LNG terminalling infrastructure needs to serve existing and expected demand and asset modernization programs.

•Wind generation includes both growth and operating expenditures. Growth expenditures include spending for the following:

◦Construction of wind-powered generating facilities at MidAmerican Energy totaling $— million and $54 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for the construction of additional wind-powered generating facilities totals $238 million for the remainder of 2026.

◦Repowering of wind-powered generating facilities at MidAmerican Energy totaling $56 million and $14 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for the repowering of wind-powered generating facilities totals $644 million for the remainder of 2026. MidAmerican Energy expects its repowered facilities to meet Internal Revenue Service guidelines for the re-establishment of PTCs under the prevailing wage and apprenticeship guidelines for 10 years from the date the facilities are placed in-service.

•Solar generation and electric battery storage include growth expenditures, including spending for the following:

◦Construction and operation of solar-powered generating facilities at MidAmerican Energy totaling $12 million and $— million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending totals $150 million for the remainder of 2026.

◦Construction of solar-powered generating facilities and co-located battery storage at the Nevada Utilities. Spending for the solar-powered generating facilities totaled $63 million and $61 million, respectively, for the three-month periods ended March 31, 2026 and 2025. Planned spending for the solar-powered generating facility totals $138 million for the remainder of 2026. Construction includes expenditures for a 400-MW solar photovoltaic facility with an additional 400 MWs of co-located battery storage that is being developed in Churchill County, Nevada with ownership share approved by the PUCN of 10% for Nevada Power and 90% for Sierra Pacific. Commercial operation of the solar facility is expected by early 2027 and the co-located battery storage reached commercial operation in March 2026.

◦Construction of solar-powered generating facilities and co-located battery storage at BHE Renewables. Spending for the solar-powered generating facilities totaled $5 million and $12 million, respectively, while spending for the co-located battery storage totaled $3 million and $17 million, respectively, for the three-month periods ended March 31, 2026 and 2025. Planned spending for the solar-powered generating facilities and co-located battery storage total $84 million and $39 million, respectively, for the remainder of 2026. Construction includes expenditures for a 48-MW solar photovoltaic facility with an additional 46 MWs of co-located battery storage that will be developed in Kern County, California, with commercial operation expected in 2026 and a 106-MW solar photovoltaic facility with an additional 50 MWs of co-located battery storage located in Jackson County, West Virginia, with commercial operation being completed in three phases between 2026 and 2027.

◦Construction of solar-powered generating facilities and co-located battery storage at BHE Montana. Spending for the solar-powered generating facilities totaled $8 million and $— million, respectively, while spending for the co-located battery storage totaled $6 million and $9 million, respectively, for the three-month periods ended March 31, 2026 and 2025. Planned spending for the solar-powered generating facilities and battery storage total $167 million and $6 million, respectively, for the remainder of 2026. Construction includes expenditures for a 130-MW solar photovoltaic facility with commercial operation expected in 2026 and a 75 MWs of battery storage that was put into service in January 2026 located in Glacier and Toole Counties in Montana and Ethridge, Montana, respectively.

40

---

•Wildfire prevention includes growth and operating expenditures, including spending for the following:

◦Expenditures at PacifiCorp totaling $138 million and $170 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for wildfire prevention totals $348 million for the remainder of 2026, and is comprised of reducing wildfire risk in the fire high consequence areas by conversion of overhead systems to underground, replacing overhead bare wire conductor with covered conductors, replacing traditional fuses with non-expulsion fuses and deployment of advanced protection devices for faster fault detection. The efforts will also include an expansion of the weather station network and predictive tools for situational awareness across the entire service territory.

◦Expenditures at the Nevada Utilities totaling $11 million and $6 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for wildfire prevention totals $113 million for the remainder of 2026, and is comprised of projects included in a comprehensive natural disaster protection plan filed and approved by the PUCN. These projects include, but are not limited to, rebuilding distribution lines with covered conductor, converting overhead distribution lines to underground and copper wire and pole replacement projects.

•Other includes both growth and operating expenditures including spending for routine expenditures for generation and other infrastructure needed to serve existing and expected demand, natural gas distribution, technology, and environmental spending relating to emissions control equipment and the management of coal combustion residuals.

Material Cash Requirements

As of March 31, 2026, there have been no material changes in cash requirements from the information provided in Item 7 of the Company's Annual Report on Form 10-K for the year ended December 31, 2025, other than those disclosed in Notes 6 and 10 of the Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q.

Regulatory Matters

BHE's regulated subsidiaries and certain affiliates are subject to comprehensive regulation. The discussion below contains material developments to those matters disclosed in Item 1 of each Registrant's Annual Report on Form 10-K for the year ended December 31, 2025, and new regulatory matters occurring in 2026.

PacifiCorp

Utah

In November 2025, PacifiCorp filed an application to create a catastrophic wildfire fund authorized by Utah statute. The fire fund would serve as a supplement to other forms of insurance to manage liabilities associated with catastrophic fire events in Utah that are not otherwise covered by insurance. In March 2026, the UPSC issued a notice of legal conclusion that determined that the surcharge for a fire fund could not be implemented outside of a general rate case. This docket will remain active to make findings and determinations regarding the catastrophic wildfire fund in advance of the next general rate case.

Oregon

In April 2025, PacifiCorp filed a renewable adjustment clause application with the OPUC to recover the full costs of certain wind‑powered generating facilities and associated transmission lines that are being only partially recovered as a result of the December 2024 general rate case order or that were placed into service subsequent to the rate effective date of the last general rate case. The application sought a rate increase of $51 million, or 2.5%, effective January 1, 2026. In December 2025, the OPUC approved recovery of the wind-powered generating facilities but not the associated transmission lines, citing that the transmission costs could only be recovered in a general rate case. The filing resulted in a rate increase of $40 million, which is a 2.2% increase for non-residential customers effective January 1, 2026, and a 1.7% increase, for residential customers effective April 1, 2026. In February 2026, PacifiCorp filed an application for reconsideration with the OPUC regarding the decision to exclude recovery of the transmission lines that the OPUC denied in March 2026.

California

In February 2026, PacifiCorp filed an application to recover over $340 million associated with the wildfire expense memorandum account representing claims costs paid and legal expense incurred to resolve third-party claims arising from the California portion of the Slater Fire and the 2022 McKinney Fire.

41

---

FERC

PacifiCorp's wholesale transmission rates are set annually using formula rates approved by the FERC and are updated annually. In May 2024, PacifiCorp published the 2024 annual update of its transmission formula rate in FERC Docket No. ER24-2004-000 pursuant to its formula rate implementation protocols. The 2024 formula rate update included the impacts of approximately $1,677 million of accrued losses, net of expected insurance recoveries associated with the Wildfires recognized during the year ended December 31, 2023, among other adjustments. Pursuant to the formula rate implementation protocols, PacifiCorp transmission customers are permitted to lodge "preliminary challenges" to the formula rate updates, which provides an informal basis upon which PacifiCorp and the transmission customers may exchange certain information and engage in discussions in order to provide further context to the rates resulting from the updates. Transmission customers are ultimately permitted to lodge "formal challenges" to the formula rate update with the FERC in the event preliminary discussions are not fruitful or do not resolve outstanding issues, and the FERC has an established process to resolve formal challenges. In June 2025, several PacifiCorp transmission customers filed formal challenges with the FERC, largely seeking to disallow PacifiCorp's recovery of the portion of losses associated with the Wildfires allocable to transmission customers through the formula rate and other, less substantive expenses. In August 2025, PacifiCorp filed a response and procedural motion with the FERC to dismiss the formal challenges on the basis that the formal challenges lack merit and do not support finding that PacifiCorp's Wildfires losses were imprudently incurred. In September 2025, those transmission customers who filed the formal challenges filed responses to PacifiCorp's filing. In October 2025, PacifiCorp filed an additional response with the FERC. In April 2026, PacifiCorp filed a motion to lodge the Oregon Court of Appeals opinion reversing and remanding the James liability verdict. PacifiCorp will continue to utilize the FERC-established process to resolve all outstanding issues related to its 2024 annual update. The matter is pending before the FERC.

2026 PacifiCorp Inter-Jurisdictional Allocation Protocol

In August 2025, PacifiCorp filed applications with the UPSC, the OPUC, the WPSC and the IPUC for approval of PacifiCorp's 2026 Inter-Jurisdictional Cost Allocation Protocol ("2026 Protocol"). The 2026 Protocol is intended to supersede the 2020 PacifiCorp Inter-Jurisdictional Allocation Protocol for Utah, Oregon, Wyoming, Idaho and California, and align with the changes proposed in the Washington 2026 Protocol, filed with the April 2025 power cost only rate case. This filing is the first phase in a multi-phased process to transition PacifiCorp's cost-allocation methodology to accommodate diverging resource portfolios and changes to operations needed to address individual state energy policies. If approved, the 2026 Protocol will be effective for new regulatory filings beginning January 1, 2026. The CPUC will consider the 2026 Protocol as part of PacifiCorp's next general rate case filed in California. In December 2025, PacifiCorp filed deferral applications with the UPSC, the OPUC, the WPSC and the IPUC for net impacts of the reallocation of resources required to implement the 2026 Protocol as of January 1, 2026, while approval of the 2026 Protocol is pending in the respective states. In February 2026, PacifiCorp filed motions to suspend the procedural schedules in the respective states to assess the effects of the Washington service area sale described below on the proposed 2026 Protocol that were granted by the four commissions in February and March 2026.

Sale of Washington Service Area and Certain Washington-based Assets

In March and April 2026, PacifiCorp filed applications and supporting testimony with the UPSC, the OPUC, the WPSC, the WUTC, the IPUC and the CPUC for authority to sell PacifiCorp's Washington service area and certain Washington-based generation, transmission and distribution assets, as applicable, to Portland General Electric Company and its affiliate Gem Sub LLC. The WUTC application was filed jointly with the buyer, committing to provide $84 million of rate credits to Washington customers to help offset the incremental costs of a temporary power purchase agreement between PacifiCorp and Gem Sub LLC that will support system reliability and continuity of operations following the close of the transaction and to address the change in rate base associated with the transaction. In the filings, PacifiCorp proposes to assign customers a portion of each state's allocated share of the amount received in excess of the net book value of the assets to be sold. PacifiCorp has requested each commission's approval by March 1, 2027. PacifiCorp will also seek approval from the FERC under certain requirements of the Federal Power Act. Refer to Note 3 of the Notes to Consolidated Financial Statements of Berkshire Hathaway Energy in Part I, Item 1 of this Form 10-Q, and to Note 3 of the Notes to Consolidated Financial Statements of PacifiCorp in Part I, Item 1 of this Form 10-Q for additional information regarding the transaction.

42

---

MidAmerican Energy

Illinois

In March 2026, MidAmerican Energy filed a request with the Illinois Commerce Commission ("ICC") seeking an increase in its Illinois retail electric rates based on a future test year. If approved as filed, the request would increase annual revenues by approximately $41 million, or 26.0%. The filing includes recovery of investments related to system reliability, new systems and technologies, and compliance with evolving safety and regulatory standards. MidAmerican Energy has requested that any approved increase be phased in over a two-year period. The filing also proposes a revenue adjustment mechanism intended to reduce revenue volatility associated with weather and usage variability. The outcome and timing of the proceeding are subject to ICC review and approval and could differ materially from MidAmerican Energy's request.

In March 2026, MidAmerican Energy filed a request with the ICC seeking an increase in its Illinois natural gas rates based on a future test year. If approved as filed, the request would increase annual revenues by approximately $9 million, or 12.2%. The filing includes recovery of investments related to system reliability, new systems and technologies, and compliance with evolving safety and regulatory standards. The filing also proposes a revenue adjustment mechanism intended to reduce revenue volatility associated with weather and usage variability. The outcome and timing of the proceeding are subject to ICC review and approval and could differ materially from MidAmerican Energy's request.

NV Energy (Nevada Power and Sierra Pacific)

Wildfire Self-Insurance Policy Filing

In January 2025, the Nevada Utilities filed applications for approval of the establishment and associated cost recovery of a Wildfire Self-Insurance Policy. The applications request that the PUCN issue an order determining that it is reasonable and prudent for the Nevada Utilities to establish a $500 million wildfire self-insurance policy (the "Policy") in order to have additional wildfire liability insurance in place in the event that a catastrophic wildfire in Nevada is alleged to be caused or exacerbated by the utility equipment. The Policy would provide $500 million in additional coverage for the Nevada Utilities for third-party claims, and it would be in excess to the commercial wildfire liability insurance the Nevada Utilities possess. In addition, the applications request approval to collect the costs for the Policy in rates over a ten-year period. Hearings before the Commission concluded in June 2025. In July 2025, the PUCN issued an order that approved the application in part and denied the application in part. The PUCN found that $1.0-$1.5 billion in insurance coverage is a prudent range for the Nevada Utilities based on its wildfire risk profile and that the Nevada Utilities sufficiently supported its initial request for an additional $500 million of excess insurance. However, the PUCN also determined that additional information is necessary to assess whether the self-insurance policy proposed by the Nevada Utilities is prudent under the circumstances and reasonable considering other options, if any. The Nevada Utilities filed the additional information requested by the PUCN in October 2025. In March 2026, the PUCN made a change to the procedural schedule and has set a hearing in June 2026 to assess the prudency of self-insurance.

Natural Disaster Protection Plan (NDPP)

In February 2026, the Nevada Utilities filed with the PUCN a joint application for approval of their Joint Natural Disaster Protection Plan for the period 2027-2029. The plan outlines proposed investments and initiatives of approximately $410 million for 2027 through 2029 to mitigate wildfire and other natural disaster risks, strengthen system reliability, and build a more resilient energy future. The plan prioritizes public safety, long-term risk reduction, rapid response and greater resilience for customers and the communities the company serves. The Natural Disaster Protection Plan details the Nevada Utilities' proposals and programs across several key areas to include: risk-based decision-making, situational awareness, operational practices and emergency response, inspections and corrections, vegetation management, system hardening, and community engagement. These efforts are designed to help the Nevada Utilities mitigate wildfire and other natural disaster risks, strengthen system reliability and continue building a more resilient energy future for Nevada. A hearing on the joint application is scheduled for August 2026.

43

---

BHE Pipeline Group

Northern Natural Gas

In July 2025, Northern Natural Gas filed a general rate case that proposed an overall annual cost-of-service of $1.6 billion. This is an increase of $286 million above the cost-of-service filed in its 2022 rate case of $1.3 billion, largely due to higher depreciation expense and return allowance of $165 million from increased rate base and an increase in depreciation and negative salvage rates, and increased operations and maintenance expenses of $96 million. Northern Natural Gas requested increases in various rates, including transportation and storage reservation rates. In January 2026, the FERC approved Northern Natural Gas' filing to implement interim rates effective January 1, 2026, subject to refund and the outcome of hearing procedures. In March 2026, a settlement agreement supported by most participating parties was filed with the FERC to resolve all pending issues in the rate case; however, certain other parties have filed comments in opposition to the settlement agreement. The settlement agreement provides for increased Market Area transportation reservation rates of 30%, increased Field Area transportation reservation rates of 37%, and increased storage reservation rates of 13% from the rates that were in effect in 2025. The settlement also provides for a moratorium on Section 4 and Section 5 rate actions until July 1, 2027. The settlement rates were implemented effective February 1, 2026, and Northern Natural Gas' provision for rate refunds for January 2026 totaled $27 million. Should any parties remain opposed to settlement, a FERC procedural schedule may be reinstated, and the case may proceed to resolve contested issues and establish rates applicable to these parties.

BHE Transmission

AltaLink

In May 2025, AltaLink filed its 2026-2027 General Tariff Application and 2023-2024 Deferral Accounts Reconciliation Application with the AUC. AltaLink amended its application in July 2025. In August 2025, AltaLink advised the AUC that it reached a negotiated settlement with customer groups for substantially all its 2026-2027 GTA revenue and the entirety of the 2023-2024 Deferral Accounts Reconciliation Application. AltaLink filed its revised GTA reflecting the terms of the negotiated settlement agreement with total amended revenue requirements of C$919 million and C$960 million for 2026 and 2027, respectively. Under the agreement, AltaLink reduced its applied-for operating expenses by C$4 million and sustaining capital expenditures by C$67 million for the 2026-2027 test period. In September 2025, the AUC approved the negotiated settlement agreement. The approved negotiated settlement marks AltaLink's fourth successful negotiated settlement over the past decade.

The negotiated settlement agreement does not include, among other items, AltaLink's 2026-2027 Wildfire Mitigation Plan and the execution and costs of the 2024-2025 Wildfire Mitigation Plan, insurance premiums, depreciation on certain asset classes, the regulatory accounting and income tax treatment of certain costs and the proposal of two deferral accounts. These items were heard in an AUC hearing in November 2025.

In March 2026, the AUC issued its decision with respect to AltaLink's 2026-2027 GTA, which provided directions on the matters excluded from the previously approved negotiated settlement agreement. The AUC approved the 2026-2027 wildfire mitigation plan capital forecast at C$41 million, representing a 39% increase from the 2024-2025 GTA decision. In April 2026, AltaLink filed its compliance filing with total revised revenue requirements of C$904 million and C$939 million for 2026 and 2027, respectively. The total revenue requirement of C$904 million for 2026, pending final AUC approval, will enable AltaLink to continue to achieve revenue requirement at or below the 2018 approved revenue requirement for eight years.

Environmental Laws and Regulations

Each Registrant is subject to federal, state, local and foreign laws and regulations regarding air quality, climate change, emissions performance standards, water quality, coal ash disposal and other environmental matters that have the potential to impact each Registrant's current and future operations. In addition to imposing continuing compliance obligations, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. These laws and regulations are administered by various federal, state, local and international agencies. Each Registrant believes it is in material compliance with all applicable laws and regulations, although many are subject to interpretation that may ultimately be resolved by the courts. The discussion below contains material developments to those matters disclosed in Item 1 of each Registrant's Annual Report on Form 10-K for the year ended December 31, 2025, and new environmental matters occurring in 2026.

44

---

Environmental Deregulation

On March 12, 2025, the EPA announced a significant deregulatory effort focused on climate change and measures that impact the energy sector. At the core of the deregulatory effort is the plan to reconsider the EPA's 2009 endangerment finding on greenhouse gases. That finding gives the EPA its authority to regulate greenhouse gas emissions by finding they threaten public health. Because the endangerment finding underpins most climate rules, rewriting the scientific finding can streamline the process of undoing those rules for power plants, motor vehicles and other sectors. In addition to the endangerment finding, the EPA announced it will review the following rules and policies relevant to the Registrants: greenhouse gas standards for power plants; methane standards for the oil and natural gas sector; greenhouse gas reporting rule; mercury and air toxics standards; steam electric effluent limitation guidelines; oil and natural gas effluent limitation guidelines; risk management program; hydrofluorocarbon phase-out rule; National Ambient Air Quality Standards for fine particulate matter; regional haze program; state and tribe implementation plans for a variety of air quality rules; exceptional events policy; coal combustion residuals rule; and the definition of waters of the U.S. The EPA has taken the following actions to implement the announcement:

•On February 19, 2026, the EPA released its final rule repealing the 2024 amendments to the Mercury and Air Toxics Standards, specifically addressing the residual risk and technology review that informed the amendments. The final rule repeals the filterable particulate matter emission standard as a surrogate for non-mercury hazardous air pollutants; the requirement to use continuous emission monitoring systems for measuring and reporting particulate matter emissions; and the mercury emissions standard for existing lignite-fueled electric generating units. The rescission of filterable particulate matter emission standard and the requirement to use continuous emission monitoring systems reduces regulatory impacts for facilities at MidAmerican Energy and PacifiCorp. The repeal of the 2024 amendments reverts the Mercury and Air Toxics Standards to the 2012 requirements of the rule. The final repeal rule has been challenged in the D.C. Circuit by environmental and health groups, 22 states and other parties. Until litigation is completed, impacts on the relevant Registrants cannot be determined.

Coal Ash Disposal

In April 2015, the EPA released a final rule to regulate the management and disposal of CCR under the RCRA. The rule regulates coal combustion residuals as non-hazardous waste under RCRA Subtitle D and establishes minimum nationwide standards for the disposal of CCR. Under the final rule, surface impoundments and landfills utilized for coal combustion residuals will need to be closed unless they can meet the more stringent regulatory requirements.

On April 9, 2026, the EPA released a proposal to amend the legacy CCR rule promulgated in 2024. The EPA proposed to revise the rule by exempting CCR dewatering structures; modifying the legacy CCR surface impoundment deferral criteria; eliminating the CCR management unit provisions; establishing new site-specific compliance pathway considerations for permitting groundwater monitoring points of compliance, corrective action cleanup levels, closure performance standards, closure timelines and CCR extraction for beneficial use during post-closure care; revising the definition of beneficial use; proposing a definition of CCR storage pile; and excluding specific beneficial uses from federal CCR regulations. As an alternative to full rescission of the CCR management unit provisions, the EPA is also seeking comment on several alternative approaches that would modify the definition and applicability of CCR management unit and the rule's associated requirements. The EPA will accept comments on the proposed amendments through June 12, 2026. The EPA also expressed an intention, in a future action, to reopen for 30 days the public comment period for the 2020 proposed rule regarding a federal CCR permit program. That rule would require owners and operators of CCR surface impoundments and landfills to obtain federal CCR permits for units located in a state without an EPA-approved state CCR permit program. Until rulemaking is completed and litigation completed, impacts on the relevant Registrants cannot be determined.

Notwithstanding the status of the final CCR rule, citizens' suits have been filed against regulated entities seeking judicial relief for contamination alleged to have been caused by releases of coal combustion residuals. Some of these cases have been successful in imposing liability upon companies if coal combustion residuals contaminate groundwater that is ultimately released or connected to surface water. In addition, actions have been filed against regulated entities seeking to require that surface impoundments containing CCR be subject to closure by removal rather than being allowed to effectuate closure in place as provided under the final rule. The Registrants are not a party to these lawsuits and until they are resolved, the Registrants cannot predict the impact on overall compliance obligations.

45

---

Federal Permitting Moratoria for Renewable Energy

On January 20, 2025, the Trump Administration released a Presidential Memorandum temporarily placing a halt on offshore wind leasing and on federal permitting for onshore wind facilities. The memorandum calls for a "temporary cessation and immediate review" of federal wind permitting for onshore wind. This directive covers "new or renewed approvals, rights of way, permits, leases, or loans for onshore or offshore wind projects" pending the completion of a comprehensive assessment and review of federal wind leasing and permitting practices. The memorandum does not provide a timeline for the Secretary of the Interior to complete its review. It also does not provide any guidance on the alleged deficiencies in the permitting process that are to be addressed. Between January and August 2025, the U.S. Department of Interior ("DOI') issued a number of orders to implement the Presidential Memorandum and enact a significant federal policy shift concerning renewable energy. Seventeen states, the District of Columbia, and the Alliance for Clean Energy New York challenged the Presidential Memorandum in U.S. District Court for the District of Massachusetts. On December 8, 2025, the court found the memorandum to be arbitrary and capricious and contrary to law and directed that it be vacated in full, meaning the ruling applies nationwide. However, the various directives issued by federal agencies limiting access to federal permits or increasing the regulatory requirements for wind and solar projects do not rely on the Presidential Memorandum, so the district court's order is not expected to directly affect them. On December 23, 2025, eight regional renewable energy trade associations filed suit in Massachusetts district court challenging six actions by federal agencies that have blocked or curtailed permitting for renewable energy projects and have requested a preliminary injunction of these actions. Applicable to the relevant Registrants, the challenged administrative actions include the DOI's policy requiring review and approval by three of the department's most senior officials for each discretionary action related to wind and solar projects; a memorandum from the Army Corps of Engineers requiring consideration of capacity density when reviewing applications for individual permits under Section 404 of the Clean Water Act and Section 10 of the Rivers and Harbors Act; and the U.S. Fish and Wildlife Service's prohibition on wind facilities obtaining permits authorizing the take of eagles under the Bald and Golden Eagle Protection Act. On April 21, 2026, the U.S. District Court for the District of Massachusetts issued a preliminary injunction blocking implementation of five of the six challenged actions, including the DOI's policy requiring three levels of review for wind and solar projects; the memoranda requiring the DOI and the Army Corps of Engineers to use a new capacity density metric when evaluating wind and solar projects on federal lands; and the DOI action restricting wind and solar projects from using the Fish and Wildlife Service's IPAC website for preliminary environmental screening. The court's order provides plaintiffs' members immediate relief from the administrative actions at issue. The U.S. Government has 60 days to appeal the preliminary injunction while merits proceedings in the district court continue. Until litigation is completed, impacts on the relevant Registrants cannot be determined.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Consolidated Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, impairment of goodwill and long-lived assets, pension and other postretirement benefits, income taxes and loss contingencies. For additional discussion of the Company's critical accounting estimates, see Item 7 of the Company's Annual Report on Form 10-K for the year ended December 31, 2025. There have been no significant changes in the Company's assumptions regarding critical accounting estimates since December 31, 2025. Refer to Note 10 of the Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q for discussion of loss contingencies related to the Wildfires.

46

---

PacifiCorp and its subsidiaries

Consolidated Financial Section

47

---

PART I

Item 1.Financial Statements

Report of Independent Registered Public Accounting Firm						49
Consolidated Balance Sheets						50
Consolidated Statements of Operations						52
Consolidated Statements of Changes in Shareholder's Equity						53
Consolidated Statements of Cash Flows						54
Notes to Consolidated Financial Statements
General						56
New Accounting Pronouncements						57
Dispositions						57
Cash and Cash Equivalents and Restricted Cash and Cash Equivalents						58
Property, Plant and Equipment, Net						59
Recent Financing Transactions						59
Income Taxes						60
Employee Benefit Plans						61
Risk Management and Hedging Activities						61
Fair Value Measurements						63
Commitments and Contingencies						65
Revenue from Contracts with Customers						68

48

---

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

PacifiCorp

Results of Review of Interim Financial Information

We have reviewed the accompanying consolidated balance sheet of PacifiCorp and subsidiaries ("PacifiCorp") as of March 31, 2026, the related consolidated statements of operations, changes in shareholders' equity, and cash flows for the three-month periods ended March 31, 2026 and 2025, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of PacifiCorp as of December 31, 2025, and the related consolidated statements of operations, comprehensive income (loss), changes in shareholders' equity, and cash flows for the year then ended (not presented herein); and in our report dated February 27, 2026, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2025, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of PacifiCorp's management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to PacifiCorp in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/ Deloitte & Touche LLP

Portland, Oregon

May 1, 2026

49

---

PACIFICORP AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions)

			As of
			March 31,						December 31,
			2026						2025
ASSETS
Current assets:
Cash and cash equivalents			$	2,169					$	73
Trade receivables, net			827						1,032
Other receivables, net			146						212
Inventories			900						920
Regulatory assets			450						669
Prepaid expenses			237						148
Assets held for sale (Note 3)			1,905						—
Other current assets			297						138
Total current assets			6,931						3,192
Property, plant and equipment, net			29,925						31,113
Regulatory assets			1,833						1,891
Other assets			956						994
Total assets			$	39,645					$	37,190

The accompanying notes are an integral part of these consolidated financial statements.

50

---

PACIFICORP AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited) (continued)

(Amounts in millions)

			As of
			March 31,						December 31,
			2026						2025
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities:
Accounts payable			$	1,325					$	1,378
Accrued interest			226						260
Accrued property, income and other taxes			104						96
Accrued employee expenses			131						105
Short-term debt			—						1,000
Current portion of long-term debt			—						100
Regulatory liabilities			78						80
Wildfires liabilities (Note 11)			160						734
Liabilities held for sale (Note 3)			249						—
Other current liabilities			483						529
Total current liabilities			2,756						4,282
Senior debt			16,079						13,193
Junior subordinated debt			1,930						841
Regulatory liabilities			2,419						2,577
Deferred income taxes			3,408						3,274
Wildfires liabilities (Note 11)			417						427
Other long-term liabilities			1,418						1,449
Total liabilities			28,427						26,043
Commitments and contingencies (Note 11)
Shareholders' equity:
Common stock - 750 shares authorized, no par value, 357 shares issued and outstanding			—						—
Additional paid-in capital			4,479						4,479
Retained earnings			6,749						6,678
Accumulated other comprehensive loss, net			(10)						(10)
Total shareholders' equity			11,218						11,147
Total liabilities and shareholders' equity			$	39,645					$	37,190

The accompanying notes are an integral part of these consolidated financial statements.

51

---

PACIFICORP AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

									Three-Month Periods
									Ended March 31,
															2026						2025
Operating revenue															$	1,808					$	1,768
Operating expenses:
Cost of fuel and energy															755						718
Operations and maintenance															463						424
Depreciation and amortization															310						299
Property and other taxes															67						59
Total operating expenses															1,595						1,500
Operating income															213						268
Other income (expense):
Interest expense															(227)						(187)
Allowance for borrowed funds															21						22
Allowance for equity funds															20						27
Interest and dividend income															27						28
Other, net															(4)						—
Total other income (expense)															(163)						(110)
Income before income tax expense (benefit)															50						158
Income tax expense (benefit)															(21)						(19)
Net income															$	71					$	177

The accompanying notes are an integral part of these consolidated financial statements.

52

---

PACIFICORP AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS' EQUITY (Unaudited)

(Amounts in millions)

																											Accumulated
															Additional												Other						Total
			Preferred						Common						Paid-in						Retained						Comprehensive						Shareholders'
			Stock						Stock						Capital						Earnings						Loss, Net						Equity
Balance, December 31, 2024			$	2					$	—					$	4,479					$	6,040					$	(9)					$	10,512
Net income			—						—						—						177						—						177
Preferred stock redemption			(1)						—						—						(1)						—						(2)
Balance, March 31, 2025			$	1					$	—					$	4,479					$	6,216					$	(9)					$	10,687
Balance, December 31, 2025			$	—					$	—					$	4,479					$	6,678					$	(10)					$	11,147
Net income			—						—						—						71						—						71
Balance, March 31, 2026			$	—					$	—					$	4,479					$	6,749					$	(10)					$	11,218

The accompanying notes are an integral part of these consolidated financial statements.

53

---

PACIFICORP AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Cash flows from operating activities:
Net income			$	71					$	177
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization			310						299
Allowance for equity funds			(20)						(27)
Net power cost deferrals			(57)						(112)
Amortization of net power cost deferrals			225						206
Other changes in regulatory assets and liabilities			2						(11)
Deferred income taxes and amortization of investment tax credits			126						(9)
Other, net			10						5
Changes in other operating assets and liabilities:
Trade receivables, other receivables and other assets			171						16
Inventories			(15)						(27)
Derivative collateral, net			(27)						5
Prepaid expenses			(97)						27
Accrued property, income and other taxes, net			(126)						14
Accounts payable and other liabilities			(52)						(59)
Wildfires insurance receivable			—						98
Wildfires liability			(584)						(114)
Net cash flows from operating activities			(63)						488
Cash flows from investing activities:
Capital expenditures			(717)						(688)
Other, net			5						5
Net cash flows from investing activities			(712)						(683)
Cash flows from financing activities:
Proceeds from senior debt			2,885						—
Proceeds from junior subordinated debt			1,089						842
Repayments of senior debt			(100)						—
Net repayments of short-term debt			(1,000)						(240)
Redemption of preferred stock			—						(2)
Other, net			(4)						(2)
Net cash flows from financing activities			2,870						598
Net change in cash and cash equivalents and restricted cash and cash equivalents			2,095						403
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period			95						61
Cash and cash equivalents and restricted cash and cash equivalents at end of period			$	2,190					$	464

 

The accompanying notes are an integral part of these consolidated financial statements.

54

---

55

---

PACIFICORP AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    General

PacifiCorp, which includes PacifiCorp and its subsidiaries, is a U.S. regulated electric utility company serving retail customers, including residential, commercial, industrial, irrigation and other customers in portions of Utah, Oregon, Wyoming, Washington, Idaho and California. PacifiCorp owns, or has interests in, a number of thermal, hydroelectric, wind-powered and geothermal generating facilities, as well as electric transmission and distribution assets. PacifiCorp also buys and sells electricity on the wholesale market with other utilities, energy marketing companies, financial institutions and other market participants. PacifiCorp is subject to comprehensive state and federal regulation. PacifiCorp's subsidiaries support its electric utility operations by providing coal mining services. PacifiCorp is an indirect subsidiary of Berkshire Hathaway Energy Company ("BHE"), a holding company based in Iowa that has investments in subsidiaries principally engaged in energy businesses. BHE is a wholly owned subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The accompanying Consolidated Financial Statements and Notes to Consolidated Financial Statements should be read in conjunction with PacifiCorp's Annual Report on Form 10-K for the year ended December 31, 2025. The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2026, and for the three-month periods ended March 31, 2026 and 2025. The Consolidated Statements of Comprehensive Income (Loss) have been omitted as net income (loss) materially equals comprehensive income (loss) for the three-month periods ended March 31, 2026 and 2025. The results of operations for the three-month period ended March 31, 2026, are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in PacifiCorp's Annual Report on Form 10-K for the year ended December 31, 2025, describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in PacifiCorp's accounting policies or its assumptions regarding significant accounting estimates during the three-month period ended March 31, 2026. Refer to Note 11 for discussion of loss contingencies related to the Oregon and Northern California 2020 wildfires (the "2020 Wildfires") and the wildfire that began in the Oak Knoll Ranger District of the Klamath National Forest in Siskiyou County, California in July 2022 (the "2022 McKinney Fire"), collectively referred to as the "Wildfires." Refer to Note 3 for information regarding assets and liabilities held for sale.

Segment Information

PacifiCorp currently has one reportable segment, its regulated electric utility operations, which derives its revenue from regulated retail sales of electricity to residential, commercial, industrial and irrigation customers and from wholesale sales. PacifiCorp's chief operating decision maker ("CODM") is its Chief Executive Officer. Net income, as reported on the Consolidated Statements of Operations, is considered by the CODM in allocating resources and capital. When making decisions about the allocation of resources and capital, the CODM generally considers actual results versus historical results, budgets or forecasts, as well as unique risks and opportunities. The segment expense information regularly provided to the CODM aligns with the captions presented on the Consolidated Statements of Operations. PacifiCorp's segment capital expenditures are reported on the Consolidated Statements of Cash Flows as capital expenditures. PacifiCorp's segment assets are reported on the Consolidated Balance Sheet as total assets.

56

---

(2)    New Accounting Pronouncements

In November 2024, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures Subtopic 220-40, "Disaggregation of Income Statement Expenses" which addresses requests from investors for more detailed information about certain expenses and requires disclosure of the amounts of purchases of inventory, employee compensation, depreciation and intangible asset amortization included in each relevant expense caption presented on the income statement. This guidance, as clarified in ASU 2025-01, is effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. Early adoption is permitted and should be applied on a prospective basis, however retrospective application is permitted. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

In December 2025, the FASB issued ASU No. 2025-10, Government Grants Topic 832, "Accounting for Government Grants Received by Business Entities" which establishes accounting for government grants received by an entity, including guidance for a grant related to an asset and a grant related to income. This guidance also requires, consistent with current disclosure requirements, that an entity provide disclosures including the nature of the government grant received, the accounting policies used to account for the grant, and significant terms and conditions of the grant. This guidance is effective for interim and annual reporting periods beginning after December 15, 2028. Early adoption is permitted and can be applied using either a modified prospective approach, a modified retrospective approach or a retrospective approach. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

(3)    Dispositions

On February 15, 2026, PacifiCorp and Portland General Electric Company and an affiliate of Portland General Electric Company (together, the "PGE Entities") entered into an Asset Purchase and Service Area Transfer Agreement (the "Sale Agreement") to sell to the PGE Entities certain PacifiCorp assets and liabilities associated with PacifiCorp's Washington operations for a sales price of $1.9 billion in cash plus additional cash consideration for the value of specified assets to be delivered at closing, subject to customary purchase price adjustments (the "Transaction").

The Transaction assets and liabilities are associated with PacifiCorp's retail service area in Washington and include certain related distribution assets and infrastructure, as well as PacifiCorp's Chehalis combined cycle natural gas-fueled generating facility located in Chehalis, Washington, Goodnoe Hills wind-powered generating facility located in Goldendale, Washington, and Marengo wind-powered generating facility located in Dayton, Washington.

The Transaction has been approved by PacifiCorp's board of directors but is subject to customary closing conditions including (i) the expiration or termination of the waiting period and other required approvals under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, and (ii) the receipt of all necessary approvals, waivers and rulings from the Federal Energy Regulatory Commission ("FERC") and each of PacifiCorp's six state public utility commissions. In March and April 2026, PacifiCorp filed for approval of the Transaction and associated disposition of assets with each of its state public utility commissions, requesting approval by March 1, 2027. PacifiCorp expects to file with the FERC in June 2026 under applicable sections of the Federal Power Act and expects approval will be received within the timeframe requested of the state public utility commissions. The Transaction is expected to close shortly after approvals are received.

The Sale Agreement contains certain termination rights, including if the Transaction is not consummated by August 15, 2027, (subject to a six month extension to the extent certain regulatory approvals have not been received as of such date), and provides that upon termination of the Sale Agreement under certain specified circumstances, the terminating party would be required to pay the other party a termination fee of $35 million.

As a result of the Transaction, PacifiCorp has presented the associated assets and liabilities as held for sale as of March 31, 2026, on the Consolidated Balance Sheets within current assets and current liabilities due to the expected timing of close of the Transaction. As the Transaction does not represent a strategic shift that will have a major impact on PacifiCorp's operations or financial results based on the scale of PacifiCorp's Washington operations and retail service territory relative to its overall operations and retail service territory, the Transaction does not qualify for presentation as discontinued operations.

57

---

As the carrying value of the associated assets and liabilities are less than fair value less costs to sell, no loss has been recorded as a result of the Transaction. PacifiCorp continues to depreciate the property, plant and equipment included in the Transaction as it will continue to operate the assets and serve PacifiCorp's Washington customers through closing of the Transaction, during which time it will continue to recover in retail rates the associated depreciation expense and return on investment, and the continued depreciation will be reflected in the carry-over basis of the assets upon closing.

The assets and liabilities held for sale as presented in Assets held for sale and Liabilities held for sale on the Consolidated Balance Sheets as of March 31, 2026, are as follows:

Assets held for sale:
Trade receivables, net						$	111
Property, plant and equipment, net:
Generation			860
Transmission			320
Distribution			750
Intangible plant and other			67
Accumulated depreciation and amortization			(455)
Construction work-in-progress			46
Property, plant and equipment, net						1,588
Regulatory assets						154
Other assets						52
Total assets held for sale						$	1,905
Liabilities held for sale:
Regulatory liabilities						$	200
Other liabilities						49
Total liabilities held for sale						$	249

Regulatory assets include amounts associated with deferred net power costs and unrealized loss on regulated derivative contracts for which the underlying contracts will transfer to the Buyer. Other assets and other liabilities include inventories, certain prepaid expenses, derivative balances, lease balances, asset retirement obligation balances and transmission deposits. Regulatory liabilities include amounts associated with cost of removal and excess deferred income tax liability balances.

(4)    Cash and Cash Equivalents and Restricted Cash and Cash Equivalents

Cash equivalents consist of funds invested in money market mutual funds, U.S. Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted cash and cash equivalents consist substantially of funds representing vendor retention, nuclear decommissioning and environmental remediation funds. A reconciliation of cash and cash equivalents and restricted cash and cash equivalents as presented on the Consolidated Statements of Cash Flows is outlined below and disaggregated by the line items in which they appear on the Consolidated Balance Sheets (in millions):

			As of
			March 31,						December 31,
			2026						2025
Cash and cash equivalents			$	2,169					$	73
Restricted cash and cash equivalents included in other current assets			18						19
Restricted cash included in other assets			3						3
Total cash and cash equivalents and restricted cash and cash equivalents			$	2,190					$	95

58

---

(5)    Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

									As of
									March 31,						December 31,
			Depreciable Life						2026						2025
Utility plant:
Generation			15 - 59 years						$	14,272					$	15,114
Transmission			60 - 90 years						11,425						11,732
Distribution			20 - 75 years						10,587						11,127
Intangible plant and other			2 - 75 years						2,605						2,667
Utility plant in-service									38,889						40,640
Accumulated depreciation and amortization									(12,617)						(12,875)
Utility plant in-service, net									26,272						27,765
Nonregulated, net of accumulated depreciation and amortization			34 - 75 years						18						18
									26,290						27,783
Construction work-in-progress									3,635						3,330
Property, plant and equipment, net									$	29,925					$	31,113

Government Grants

As of March 31, 2026, and December 31, 2025, approximately $58 million and $50 million, respectively, of federal grant funds reduced additions to property, plant and equipment – net on the Consolidated Balance Sheets. During the three-month periods ended March 31, 2026 and 2025, approximately $2 million and $13 million, respectively, of federal grant funds reduced operating expenses on the Consolidated Statements of Operations.

(6)    Recent Financing Transactions

Senior Debt

In February 2026, PacifiCorp issued $400 million of 4.25% First Mortgage Bonds due March 2029.

In March 2026, PacifiCorp issued $300 million of its 4.65% First Mortgage Bonds due April 2029, $550 million of its 5.10% First Mortgage Bonds due April 2031, $800 million of its 5.45% First Mortgage Bonds due April 2033, and $850 million of its 5.80% First Mortgage Bonds due April 2036.

Junior Subordinated Debt

In February 2026, PacifiCorp issued $1.1 billion of its 7.125% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due August 2056. PacifiCorp will pay interest on the junior subordinated notes at a rate of 7.125% through August 2031, subject to a reset every five years, not to reset below 7.125%.

59

---

Credit Facilities

In April 2026, PacifiCorp entered into a letter of credit agreement under which letters of credit will be made available solely to provide collateral support for surety bonds issued pursuant to a corresponding surety arrangement for supersedeas undertakings to secure the performance and stay enforcement of trial court judgments entered against PacifiCorp relating to the James case, in each case while such judgments remain pending appeal by PacifiCorp in the Oregon Court of Appeals or the Oregon Supreme Court. Refer to Note 11 for information regarding the Oregon Court of Appeals opinion issued in April 2026 associated with the James case. The letter of credit agreement provides for a two-year standby letter of credit facility for PacifiCorp in an aggregate stated amount of up to $2.55 billion. In conjunction with the letter of credit agreement, PacifiCorp entered into a committed surety facility set forth in a term sheet with an initial aggregate capacity of $2.55 billion, not to exceed availability under the letter of credit agreement, and related indemnity agreement under which the surety party is committed to issue surety bonds from time to time for PacifiCorp to secure the supersedeas undertakings described above. The surety facility must be fully secured by letters of credit. If 91 days prior to the applicable termination date of any letter of credit issued under the arrangements described above, any letter of credit obligations remain outstanding, PacifiCorp will be required to provide cash collateral to secure outstanding letter of credit obligations in an amount equal to 103% of such obligations. In April 2026, PacifiCorp received the necessary approvals from the Oregon Public Utility Commission and the Idaho Public Utilities Commission.

(7)    Income Taxes

Berkshire Hathaway includes BHE and its subsidiaries in its U.S. federal income tax return and BHE includes its subsidiaries in certain state income tax returns. Consistent with established regulatory practice, PacifiCorp's provision for federal and state income tax has been computed on a stand-alone basis, and substantially all of its currently payable or receivable income tax is remitted to or received from BHE pursuant to a tax allocation agreement. PacifiCorp made net cash payments for state income taxes to BHE totaling $2 million for each of the three-month periods ended March 31, 2026 and 2025. As of March 31, 2026, federal and state income taxes receivable from BHE were $228 million. As of December 31, 2025, federal income taxes receivable from BHE were $94 million and state income taxes payable to BHE were $16 million.

A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income before income tax expense (benefit) is as follows (amounts in millions):

									Three-Month Periods
									Ended March 31,
															2026												2025
																											Amount						Percent						Amount						Percent
U.S. federal statutory income tax rate																											$	10					21.0		%				$	33					21.0		%
State and local income taxes, net of federal income tax																											4						8.2						8						4.9
Energy-related tax credits																											(30)						(60.3)						(47)						(29.7)
Effects of ratemaking(1)																											(5)						(11.3)						(13)						(8.4)
Effective income tax rate																											$	(21)					(42.4)		%				$	(19)					(12.2)		%

(1)Effects of ratemaking is primarily attributable to activity associated with excess deferred income taxes.

Energy-related tax credits relate primarily to production tax credits ("PTC") earned by PacifiCorp's wind-powered generating facilities. Federal renewable electricity PTCs are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in-service.

60

---

(8)    Employee Benefit Plans

Net periodic benefit cost (credit) for the pension and other postretirement benefit plans included the following components (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Pension:
Interest cost															$	9					$	9
Expected return on plan assets															(11)						(11)
Net amortization															2						2
Net periodic benefit cost (credit)															$	—					$	—
Other postretirement:
Service cost															$	—					$	—
Interest cost															3						3
Expected return on plan assets															(3)						(3)
Net amortization															(1)						(1)
Net periodic benefit credit															$	(1)					$	(1)

Amounts other than the service cost for pension and other postretirement benefit plans are recorded in other, net on the Consolidated Statements of Operations. Employer contributions to the pension and other postretirement benefit plans are expected to be $4 million and $— million, respectively, during 2026. As of March 31, 2026, $1 million of contributions had been made to the pension plans.

(9)    Risk Management and Hedging Activities

PacifiCorp is exposed to the impact of market fluctuations in commodity prices and interest rates. PacifiCorp is principally exposed to electricity, natural gas, coal and fuel oil commodity price risk as it has an obligation to serve retail customer load in its service territories. PacifiCorp's load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity and wholesale electricity that is purchased and sold. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather, market liquidity, generating facility availability, customer usage, storage, and transmission and transportation constraints. Interest rate risk exists on variable-rate debt and future debt issuances. PacifiCorp does not engage in a material amount of proprietary trading activities.

PacifiCorp has established a risk management process that is designed to identify, assess, manage and report on each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, PacifiCorp uses commodity derivative contracts, which may include forwards, futures, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. PacifiCorp manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed-rate long-term debt and by monitoring market changes in interest rates. Additionally, PacifiCorp may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, to mitigate PacifiCorp's exposure to interest rate risk. No interest rate derivatives were in place during the periods presented. PacifiCorp does not hedge all of its commodity price and interest rate risks, thereby exposing the unhedged portion to changes in market prices. Refer to Note 10 for additional information related to the fair value measurements associated with derivative contracts.

61

---

The following table, which reflects master netting arrangements and excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of PacifiCorp's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Consolidated Balance Sheets (in millions):

			Other												Other						Other
			Current						Other						Current						Long-term
			Assets						Assets						Liabilities						Liabilities						Total
As of March 31, 2026
Not designated as hedging contracts(1):
Commodity assets			$	3					$	—					$	3					$	—					$	6
Commodity liabilities			—						—						(97)						(20)						(117)
Total			3						—						(94)						(20)						(111)
Cash collateral receivable			—						—						65						—						65
Total derivatives - net basis			$	3					$	—					$	(29)					$	(20)					$	(46)
As of December 31, 2025
Not designated as hedging contracts(1):
Commodity assets			$	5					$	—					$	4					$	1					$	10
Commodity liabilities			—						—						(119)						(28)						(147)
Total			5						—						(115)						(27)						(137)
Cash collateral receivable			—						—						67						4						71
Total derivatives - net basis			$	5					$	—					$	(48)					$	(23)					$	(66)

(1)PacifiCorp's commodity derivatives are generally included in rates. As of March 31, 2026, a regulatory asset of $111 million was recorded related to the net derivative liability of $111 million. As of December 31, 2025, a regulatory asset of $137 million was recorded related to the net derivative liability of $137 million.

The following table reconciles the beginning and ending balances of PacifiCorp's net regulatory assets (liabilities) and summarizes the pre-tax gains and losses on commodity derivative contracts recognized in net regulatory assets (liabilities), as well as amounts reclassified to earnings (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Beginning balance															$	137					$	97
Changes in fair value recognized in regulatory assets															34						10
Net gains reclassified to operating revenue															7						8
Net losses reclassified to cost of fuel and energy															(67)						(34)
Ending balance															$	111					$	81

Derivative Contract Volumes

The following table summarizes the net notional amounts of outstanding commodity derivative contracts with fixed price terms that comprise the mark-to-market values as of (in millions):

			Unit of						March 31,						December 31,
			Measure						2026						2025
Natural gas purchases			Decatherms						122						147

62

---

Credit Risk

PacifiCorp is exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent PacifiCorp's counterparties have similar economic, industry or other characteristics and due to direct or indirect relationships among the counterparties. Before entering into a transaction, PacifiCorp analyzes the financial condition of each significant wholesale counterparty, establishes limits on the amount of unsecured credit to be extended to each counterparty and evaluates the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, PacifiCorp enters into netting and collateral arrangements that may include margining and cross-product netting agreements and obtains third‑party guarantees, letters of credit and cash deposits. If required, PacifiCorp exercises rights under these arrangements, including calling on the counterparty's credit support arrangement.

Collateral and Contingent Features

In accordance with industry practice, certain wholesale energy agreements, including contracts for purchases, sales and transportation of electricity, natural gas, and coal, some of which are accounted for as derivatives, contain credit support provisions that in part base certain collateral requirements on credit ratings for senior unsecured debt as reported by one or more of the recognized credit rating agencies. These agreements may provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels ("credit-risk-related contingent features"). These agreements and other agreements that do not refer to specified rating-dependent thresholds may provide the right for counterparties to demand "adequate assurance" if there is a material adverse change in PacifiCorp's creditworthiness. These rights can vary by contract and by counterparty. As of March 31, 2026, PacifiCorp's issuer credit ratings for senior unsecured debt from the recognized credit rating agencies were investment grade.

The aggregate fair value of PacifiCorp's derivative contracts in liability positions with specific credit-risk-related contingent features totaled $117 million and $145 million as of March 31, 2026, and December 31, 2025, respectively, for which PacifiCorp had posted collateral of $65 million and $71 million, respectively, in the form of cash deposits. If all credit-risk-related contingent features for derivative contracts in liability positions had been triggered as of March 31, 2026, and December 31, 2025, PacifiCorp would have been required to post $49 million and $69 million, respectively, of additional collateral.

PacifiCorp's collateral requirements associated with wholesale energy agreements could fluctuate considerably due to market price volatility; changes in credit ratings; changes in legislation or regulation or other factors; and if counterparties demand adequate assurance in the event of a material adverse change in PacifiCorp's creditworthiness.

(10)    Fair Value Measurements

The carrying value of PacifiCorp's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. PacifiCorp has various financial assets and liabilities that are measured at fair value on the Consolidated Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

•Level 1 — Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that PacifiCorp has the ability to access at the measurement date.

•Level 2 — Inputs include 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 that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).

•Level 3 — Unobservable inputs reflect PacifiCorp's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. PacifiCorp develops these inputs based on the best information available, including its own data.

63

---

The following table presents PacifiCorp's financial assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions):

			Input Levels for Fair Value Measurements
			Level 1						Level 2						Level 3						Other(1)						Total
As of March 31, 2026:
Assets:
Commodity derivatives			$	—					$	6					$	—					$	(3)					$	3
Money market mutual funds			2,167						—						—						—						2,167
Investment funds			22						—						—						—						22
			$	2,189					$	6					$	—					$	(3)					$	2,192
Liabilities:
Commodity derivatives			$	—					$	(117)					$	—					$	68					$	(49)
As of December 31, 2025:
Assets:
Commodity derivatives			$	—					$	10					$	—					$	(5)					$	5
Money market mutual funds			84						—						—						—						84
Investment funds			28						—						—						—						28
			$	112					$	10					$	—					$	(5)					$	117
Liabilities:
Commodity derivatives			$	—					$	(147)					$	—					$	76					$	(71)

(1)Represents netting under master netting arrangements and a net cash collateral receivable of $65 million and $71 million as of March 31, 2026, and December 31, 2025, respectively.

Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. A discounted cash flow valuation method was used to estimate fair value. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which PacifiCorp transacts. When quoted prices for identical contracts are not available, PacifiCorp uses forward price curves. Forward price curves represent PacifiCorp's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. PacifiCorp bases its forward price curves upon market price quotations, when available, or internally developed and commercial models, with internal and external fundamental data inputs. Market price quotations are obtained from independent energy brokers, exchanges, direct communication with market participants and actual transactions executed by PacifiCorp. Market price quotations for certain major electricity and natural gas trading hubs are generally readily obtainable for the first three years; therefore, PacifiCorp's forward price curves for those locations and periods reflect observable market quotes. Market price quotations for other electricity and natural gas trading hubs are not as readily obtainable for the first three years. Given that limited market data exists for these contracts, as well as for those contracts that are not actively traded, PacifiCorp uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The estimated fair value of these derivative contracts is a function of underlying forward commodity prices, interest rates, currency rates, related volatility, counterparty creditworthiness and duration of contracts. Refer to Note 9 for further discussion regarding PacifiCorp's risk management and hedging activities.

PacifiCorp's investments in money market mutual funds and investment funds are stated at fair value. When available, PacifiCorp uses a readily observable quoted market price or net asset value of an identical security in an active market to record the fair value. In the absence of a quoted market price or net asset value of an identical security, the fair value is determined using pricing models or net asset values based on observable market inputs and quoted market prices of securities with similar characteristics.

64

---

PacifiCorp's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of PacifiCorp's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The following table presents the carrying value and estimated fair value of PacifiCorp's long-term debt (in millions):

			As of March 31, 2026												As of December 31, 2025
			Carrying						Fair						Carrying						Fair
			Value						Value						Value						Value
Long-term debt			$	18,009					$	16,575					$	14,134					$	13,005

(11)    Commitments and Contingencies

Guarantees

PacifiCorp has entered into guarantees as part of the normal course of business and the sale or transfer of certain assets. These guarantees are not expected to have a material impact on PacifiCorp's consolidated financial results.

Environmental Laws and Regulations

PacifiCorp is subject to federal, state and local laws and regulations regarding air quality, climate change, emissions performance standards, water quality, coal ash disposal, wildfire prevention and mitigation and other environmental matters that have the potential to impact its current and future operations. PacifiCorp believes it is in material compliance with all applicable laws and regulations.

Legal Matters

PacifiCorp is party to a variety of legal actions, including litigation, arising out of the normal course of business, some of which assert claims for damages in substantial amounts and are described below. For certain legal actions, parties at times may seek to impose fines, penalties and other costs.

Pursuant to ASC 450, "Contingencies," a provision for a loss contingency is recorded when it is probable a liability is likely to occur and the amount of loss can be reasonably estimated. PacifiCorp evaluates the related range of reasonably estimated losses and records a loss based on its best estimate within that range or the lower end of the range if there is no better estimate.

Wildfires

2020 Wildfires and 2022 McKinney Fire

The 2020 Wildfires occurred in September 2020, when a severe weather event with high winds contributed to several major wildfires, resulting in real and personal property and natural resource damage, personal injuries and loss of life and widespread power outages in Oregon and Northern California. The wildfires spread across certain parts of PacifiCorp's service territory and surrounding areas across multiple counties in Oregon and California, burning over 500,000 acres in aggregate and include the Santiam Canyon, Beachie Creek, South Obenchain, Echo Mountain Complex, 242, Archie Creek, Slater and other fires. The Slater fire occurred in both Oregon and California. Third-party reports for these wildfires indicate over 2,000 structures destroyed, including residences; several structures damaged; multiple individuals injured; and several fatalities.

Both the U.S. Department of Agriculture Forest Service ("USFS") and the Oregon Department of Forestry ("ODF") completed investigation reports related to a wildland fire that was first reported outside the Santiam Canyon on August 16, 2020 ("Beachie Creek Fire"), approximately three weeks before the severe weather event described above. The ODF's report concluded that embers from the pre-existing Beachie Creek Fire caused 12 fires within the Santiam Canyon. The ODF's report also found that PacifiCorp's power lines did not contribute to the overall spread of fire into the Santiam Canyon even though PacifiCorp's power lines ignited seven spot fires within the Santiam Canyon that were each suppressed.

65

---

The Beachie Creek Fire that spread into the Santiam Canyon burned approximately 193,000 acres; the South Obenchain fire burned approximately 33,000 acres; the Echo Mountain Complex fire burned approximately 3,000 acres; and the 242 fire burned approximately 14,000 acres. The James cases described below are associated with the Beachie Creek (Santiam Canyon), South Obenchain, Echo Mountain Complex and 242 fires, which are four distinct fires located hundreds of miles apart.

The 2022 McKinney Fire occurred on July 29, 2022, when a wildfire began in Siskiyou County, California within PacifiCorp's service territory, burning over 60,000 acres. Third-party reports indicate that the 2022 McKinney Fire resulted in 11 structures damaged; 185 structures destroyed, including residences; 12 injuries; and four fatalities.

Complaints and Demands Associated with the Wildfires

A significant number of complaints and demands alleging similar claims related to the Wildfires have been filed in Oregon and California, including a class action complaint in Oregon associated with 2020 Wildfires (the "James" case) for which certain jury verdicts were issued as described below. The plaintiffs seek damages for economic losses, noneconomic losses, including mental suffering, emotional distress, personal injury and loss of life, punitive damages, other damages and attorneys' fees. Several insurance carriers also filed subrogation complaints in Oregon and California with similar allegations. Additionally, PacifiCorp received correspondence from the U.S. and Oregon Departments of Justice regarding the potential recovery of certain costs and damages alleged to have occurred on federal and state lands in connection with certain of the 2020 Wildfires. As described below, substantially all outstanding complaints and demands are associated with the 2020 Wildfires, specifically the James case and the state of Oregon demands.

Substantially all amounts sought in outstanding complaints and demands filed in Oregon are associated with the James mass complaints described below, as well as stayed cases for which motions have been filed for consolidation into the James case and the state of Oregon demands. Oregon law provides for doubling of economic and property damages in the event the defendant is found to have acted with gross negligence, recklessness, willfulness or malice. Oregon law provides for trebling of damages associated with timber, shrubs and produce in the event the defendant is determined to have willfully and intentionally trespassed. For class actions, amounts specified by the plaintiffs in the complaints include amounts based on estimates of the potential class size, which ultimately may be significantly greater than estimated.

PacifiCorp has settled various claims associated with the Wildfires, including all wrongful death claims and federal government demands and complaints associated with the Wildfires. For the Archie Creek Fire, Slater Fire and 2022 McKinney Fire, settlements have been reached with substantially all plaintiffs. For the Santiam Canyon, Echo Mountain Complex, South Obenchain and 242 fires, while PacifiCorp settled claims with individual plaintiffs who were granted substitution of counsel in the James case, with the Oregon wineries and with the federal government, claims remain outstanding for a substantial number of plaintiffs associated with the James case. PacifiCorp is also actively cooperating with the Oregon Department of Justice on resolving its alleged claims. Refer below for information regarding the Oregon Court of Appeals opinion issued in April 2026 pertaining to the James class action complaint.

The James Case

On September 30, 2020, a class action complaint against PacifiCorp captioned Jeanyne James et al. v. PacifiCorp, ("James") was filed in Oregon Circuit Court in Multnomah County, Oregon ("Multnomah County Circuit Court Oregon"). The complaint was filed by Oregon residents and businesses who sought to represent a class of all Oregon citizens and entities whose real or personal property was harmed beginning on September 7, 2020, by wildfires in Oregon allegedly caused by PacifiCorp. In November 2021, the plaintiffs filed an amended complaint to limit the class to include Oregon citizens allegedly impacted by the Santiam Canyon, Echo Mountain Complex, South Obenchain and 242 fires, as well as to add claims for noneconomic damages. The amended complaint alleged that PacifiCorp's assets contributed to the Oregon wildfires occurring on or after September 7, 2020, and that PacifiCorp acted with gross negligence, among other things. The amended complaint seeks damages similar to those described above, including not less than $600 million of economic damages and in excess of $1 billion of noneconomic damages for the plaintiffs and the class.

Since the filing of the original class action complaint, several cases have been stayed pending consolidation into James and numerous James class members have been named and damages specified in various complaints. From April 2024 through January 2026, 1,760 James class members filed nine mass damages complaints in Multnomah County Circuit Court Oregon premised on the Phase I liability verdict, as described below, each referencing the original James case as the lead case. The James mass complaints make damages-only allegations seeking for each individual class member $5 million of economic damages, $25 million of noneconomic damages and punitive damages equal to 0.25 times the amount of economic and noneconomic damages, as well as doubling of economic damages. Complaints for some of the plaintiffs in the mass complaints have been dismissed, amended or re-filed.

66

---

The Multnomah County Circuit Court Oregon determined that the James case would be divided into a liability phase ("Phase I") and a damages phase ("Phase II"). In June 2023, a jury in the Phase I liability trial found PacifiCorp's conduct grossly negligent, reckless and willful as to each of the 17 named plaintiffs and the entire class. The jury awarded economic and noneconomic damages, as well as punitive damages. After the jury verdict, the Multnomah County Circuit Court Oregon doubled the Phase I plaintiffs' economic damages, in accordance with Oregon law, and added punitive damages by applying a 0.25 multiplier to the awarded economic and noneconomic damages. The Multnomah County Circuit Court Oregon granted PacifiCorp's subsequent motion to offset the damage awards by deducting insurance proceeds received by any of the plaintiffs.

PacifiCorp subsequently appealed the Phase I liability verdict, and on April 8, 2026, the verdict was reversed and remanded by the Oregon Court of Appeals, as described in more detail below.

While PacifiCorp's appeal of the Phase I verdict was pending, the Multnomah County Circuit Court Oregon held numerous Phase II trials, in which a series of juries awarded damages to groups of James class members. The majority of these trials were scheduled pursuant to a case management order called "CMO No. 11." PacifiCorp has filed notices of appeal for the subsequent jury verdicts in the Phase II trials once limited judgments are entered and any post-trial motions filed. The James jury verdicts to date have awarded total net damages of $1,252 million to 201 plaintiffs, including $133 million of doubled economic damages, $910 million of noneconomic damages, $244 million of punitive damages and partially offset by estimated insurance offsets of $35 million. To date, PacifiCorp has been required to bond the amounts awarded by the James limited judgments in order to stay payment of damages while on appeal. As of the date of this filing, PacifiCorp has posted bonds totaling $719 million associated with the limited judgments entered to date for 129 plaintiffs. Based on the April 2026 Oregon Court of Appeals opinion, the existing bonds could eventually be discharged and any future bonding requirements eliminated.

The Oregon Court of Appeals' April 2026 opinion reversing the Phase I verdict explained that the Multnomah County Circuit Court Oregon erred in instructing the jury that they could "assume that the evidence at the trial applies to all class members." The Oregon Court of Appeals further concluded that the erroneous jury instruction "was prejudicial to PacifiCorp" because it "gave rise to some likelihood that the jury reached an erroneous result." Because the Oregon Court of Appeals reversed and remanded on the instructional error issue presented in PacifiCorp's appellate brief, it did not address the majority of PacifiCorp's other appealed issues. However, the Oregon Court of Appeals emphasized that the Multnomah County Circuit Court Oregon has the authority on remand to reconsider its class certification decision and reconsider whether a single class is appropriate in this case. The Oregon Court of Appeals determined PacifiCorp was the prevailing party and awarded costs to PacifiCorp. Either party can file a petition for review with the Oregon Supreme Court within 35 days of the Oregon Court of Appeals opinion, subject to extension. Whether the Oregon Supreme Court accepts a request for review is at its discretion.

On April 9, 2026, the Multnomah County Circuit Court Oregon ordered a stay of scheduled James Phase II trials (except for a trial that began April 6, 2026, and subsequently concluded on April 13, 2026) and mandatory mediation. The Multnomah County Circuit Court Oregon asked the parties to submit briefing on the merits, scope and duration of the stay in advance of a May 22, 2026, hearing.

Estimated Losses for and Settlements Associated with the Wildfires

Based on the facts and circumstances available to PacifiCorp as of the date of this filing, including (i) cause and origin investigations; (ii) ongoing settlement and mediation activities; (iii) other litigation matters and upcoming legal proceedings; and (iv) the status of the James case, PacifiCorp recorded cumulative estimated probable losses associated with the Wildfires of $2,853 million through March 31, 2026. PacifiCorp's cumulative accrual includes estimates of probable losses for fire suppression costs, real and personal property damages, natural resource damages and noneconomic damages such as personal injury damages and loss of life damages that it is reasonably able to estimate at this time and which is subject to change as additional relevant information becomes available.

Through March 31, 2026, PacifiCorp paid $2,276 million in settlements associated with the Wildfires. As a result of the settlements, various trials have been cancelled. In April 2026, PacifiCorp made additional settlement payments related to the Wildfires totaling $4 million.

67

---

The following table presents changes in PacifiCorp's liability for estimated losses associated with the Wildfires (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Beginning balance															$	1,161					$	1,536
Payments															(584)						(114)
Ending balance															$	577					$	1,422

As of March 31, 2026 and December 31, 2025, $160 million and $734 million of PacifiCorp's liability for estimated losses associated with the Wildfires was classified as a current liability captioned Wildfires liabilities on the Consolidated Balance Sheets. The amounts reflected as current as of March 31, 2026, reflect amounts reasonably expected to be paid out within the next year based on settlements reached as well as ongoing settlement and mediation efforts. The remainder of PacifiCorp's liability for estimated losses associated with the Wildfires as of March 31, 2026 and December 31, 2025, was classified as a noncurrent liability captioned Wildfires liabilities on the Consolidated Balance Sheets.

As of March 31, 2025, PacifiCorp had received all expected insurance recoveries with the final $98 million of proceeds received during the three-month period ended March 31, 2025. No additional insurance recoveries beyond those received to date are expected to be available.

It is reasonably possible PacifiCorp will incur material additional losses beyond the amounts accrued for the Wildfires that could have a material adverse effect on PacifiCorp's financial condition. PacifiCorp is currently unable to reasonably estimate a specific range of possible additional losses that could be incurred due to the number of properties and parties involved, including claimants in the class to the James case, the variation in the types of properties and damages and the ultimate outcome of legal actions, including mediation, settlement negotiations, jury verdicts and the James appeals process, including the April 2026 Oregon Court of Appeals opinion.

(12)    Revenue from Contracts with Customers

The following table summarizes PacifiCorp's revenue from contracts with customers ("Customer Revenue") by line of business, with further disaggregation of retail by customer class (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Customer Revenue:
Retail:
Residential															$	667					$	672
Commercial															597						564
Industrial															347						344
Other retail															75						67
Total retail															1,686						1,647
Wholesale															21						13
Transmission															35						48
Other Customer Revenue															42						27
Total Customer Revenue															1,784						1,735
Other revenue															24						33
Total operating revenue															$	1,808					$	1,768

68

---

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

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of PacifiCorp during the periods included herein. Explanations include management's best estimate of the impact of weather, customer growth, usage trends and other factors. This discussion should be read in conjunction with PacifiCorp's historical unaudited Consolidated Financial Statements and Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10‑Q. PacifiCorp's actual results in the future could differ significantly from the historical results.

Results of Operations for the First Quarter of 2026 and 2025

Overview

Net income for the first quarter of 2026 was $71 million, a decrease of $106 million, compared to 2025. The decrease in net income was primarily due to higher interest expense, higher operations and maintenance expense, higher depreciation expense, lower allowances for equity and borrowed funds used during construction and higher property taxes, partially offset by slightly higher utility margin. Utility margin increased slightly primarily due to lower thermal generation costs and higher retail revenues, partially offset by lower net power cost deferrals, higher purchased electricity costs and lower wholesale sales. Retail customer volumes decreased 1.2%, primarily due to unfavorable impacts of weather and lower customer usage, partially offset by an increase in the average number of customers. Energy generated volumes decreased 1,173 gigawatt-hours, or 9%, for the first quarter of 2026 compared to 2025 primarily due to lower coal-fueled generation, lower natural-gas fueled generation and lower hydro-powered generation, partially offset by higher wind-powered generation. Wholesale electricity sales volumes increased 19 gigawatt-hours, or 2%, and energy purchased volumes increased 840 gigawatt-hours, or 21%.

Non-GAAP Financial Measure

Management utilizes various key financial measures that are prepared in accordance with GAAP, as well as non-GAAP financial measures such as utility margin, to help evaluate results of operations. Utility margin is calculated as operating revenue less cost of fuel and energy, which are captions presented on the Consolidated Statements of Operations.

PacifiCorp's cost of fuel and energy is generally recovered from its retail customers through regulatory recovery mechanisms and as a result, changes in PacifiCorp's expenses included in regulatory recovery mechanisms result in comparable changes to revenue. As such, management believes utility margin more appropriately and concisely explains results of operations rather than a discussion of revenue and cost of fuel and energy separately. Management believes the presentation of utility margin provides meaningful and valuable insight into the information management considers important to understanding the business and a measure of comparability to others in the industry.

Utility margin is not a measure calculated in accordance with GAAP and should be viewed as a supplement to and not a substitute for operating income, which is the most comparable financial measure prepared in accordance with GAAP. The following table provides a reconciliation of utility margin to operating income (in millions):

			First Quarter
			2026						2025						Change
Utility margin:
Operating revenue			$	1,808					$	1,768					$	40					2		%
Cost of fuel and energy			755						718						37						5
Utility margin			1,053						1,050						3						—
Operations and maintenance			463						424						39						9
Depreciation and amortization			310						299						11						4
Property and other taxes			67						59						8						14
Operating income			$	213					$	268					$	(55)					(21)		%

69

---

Utility Margin

A comparison of key operating results related to utility margin is as follows:

			First Quarter
			2026						2025						Change
Utility margin (in millions):
Operating revenue			$	1,808					$	1,768					$	40					2		%
Cost of fuel and energy			755						718						37						5
Utility margin			$	1,053					$	1,050					$	3					—		%
Sales (GWhs):
Residential			4,605						4,917						(312)						(6)		%
Commercial(1)			5,687						5,529						158						3
Industrial(1)			4,116						4,127						(11)						—
Other(1)			46						50						(4)						(8)
Total retail			14,454						14,623						(169)						(1)
Wholesale			1,050						1,031						19						2
Total sales			15,504						15,654						(150)						(1)		%
Average number of retail customers (in thousands)			2,157						2,127						30						1		%
Average revenue per MWh:
Retail			$	117.01					$	112.67					$	4.34					4		%
Wholesale			$	35.72					$	43.09					$	(7.37)					(17)		%
Heating degree days			3,992						4,615						(623)						(13)		%
Cooling degree days			6						1						5						* %
Sources of energy (GWhs)(1):
Coal			4,166						5,968						(1,802)						(30)		%
Natural gas			3,725						3,838						(113)						(3)
Wind(2)			3,062						2,300						762						33
Hydroelectric and other(2)			859						879						(20)						(2)
Total energy generated			11,812						12,985						(1,173)						(9)
Energy purchased			4,859						4,019						840						21
Total			16,671						17,004						(333)						(2)		%
Average cost of energy per MWh:
Energy generated(3)			$	24.28					$	25.99					$	(1.71)					(7)		%
Energy purchased			$	51.78					$	59.62					$	(7.84)					(13)		%

*    Not meaningful

(1)    GWh amounts are net of energy used by the related generating facilities.

(2)    All or some of the renewable energy attributes associated with generation from these sources may be: (a) used in future years to comply with RPS or other regulatory requirements or (b) sold to third parties in the form of renewable energy credits or other environmental commodities.

(3)    The average cost per MWh of energy generated includes only the cost of fuel associated with the generating facilities.

70

---

Quarter Ended March 31, 2026, compared to Quarter Ended March 31, 2025

Utility margin increased $3 million for the first quarter of 2026 compared to 2025 primarily due to:

•$44 million increase in retail revenue due to higher average prices, partially offset by lower volumes. Retail revenue increased primarily due to price impacts of $75 million from higher average rates, largely from tariff changes. Retail customer volumes decreased $31 million, or 1.2%, primarily due to unfavorable weather related impacts on residential and commercial customers, mainly in Utah and Oregon and decrease in residential customer usage across the service territory, except Wyoming, partially offset by an increase in the average number of commercial and residential customers across the service territory and an increase in Oregon, Utah and Washington commercial customer usage;

•$38 million of lower coal-fueled generation costs from lower volumes, partially offset by higher prices; and

•$12 million of lower natural gas-fueled generation costs from lower prices and volumes.

The increases above were partially offset by:

•$73 million of lower net power cost deferrals in accordance with established adjustment mechanisms driven by lower current quarter deferrals and higher amortization of prior deferrals;

•$12 million of higher purchased electricity costs from higher volumes, partially offset by lower average market prices; and

•$7 million decrease in wholesale revenue due to lower average market prices, partially offset by higher volumes.

Operations and maintenance increased $39 million, or 9%, for the first quarter of 2026 compared to 2025 primarily due to:

•$15 million of higher vegetation management and wildfire mitigation costs, primarily from higher amortization of prior year deferrals, and lower current year cost deferrals;

•$11 million due to lower federal grant reimbursements;

•$7 million of higher demand side management amortization driven by increased spend;

•$4 million of higher general plant and maintenance costs; and

•$4 million of higher legal fees.

The increases above were partially offset by:

•$6 million of lower insurance expense due to lower liability insurance premiums, partially offset by amortization of prior deferrals.

Depreciation and amortization increased $11 million, or 4%, for the first quarter of 2026 compared to 2025, primarily due to higher average in-service plant, partially offset by lower depreciation expense resulting from the impacts of the prior year buydown of certain plant balances.

Property and other taxes increased $8 million, or 14%, for the first quarter of 2026 compared to 2025, primarily due to higher property taxes in Oregon.

Interest expense increased $40 million, or 21%, for the first quarter of 2026 compared to 2025, primarily due to higher average long-term debt balances due to the issuance of $850 million and $1.1 billion of junior subordinated notes in March 2025 and February 2026, respectively, and the issuance of $400 million and $2.5 billion of first mortgage bonds in February 2026 and March 2026, respectively, higher interest expense on finance leases and higher short-term debt balances.

Allowance for borrowed and equity funds decreased $8 million, or 16%, for the first quarter of 2026 compared to 2025, primarily due to lower qualified construction work-in-progress balances, partially offset by higher rates.

Income tax benefit increased $2 million, or 11%, for the first quarter of 2026 compared to 2025. The effective tax rate was (42)% and (12)% for the three-month periods ended March 31, 2026 and 2025, respectively. The $2 million increase was primarily due to lower pre-tax income, partially offset by lower PTCs from PacifiCorp's wind-powered generating facilities and lower benefit from the effects of ratemaking.

71

---

Liquidity and Capital Resources

Overview

PacifiCorp's liquidity has been impacted by the Wildfires, resulting in increased debt and additional financing activities to fund its operations, implement its business strategy, make interest payments, make scheduled repayments of long-term debt, finance its capital investments and fund potential future settlements associated with the Wildfires. To help mitigate PacifiCorp's liquidity pressures, BHE has indicated that it will suspend dividends for the next several years in order to allow PacifiCorp to accumulate cash that may be necessary in the event of additional future settlements associated with the Wildfires and to improve its capital structure.

As of March 31, 2026, PacifiCorp's total net liquidity was as follows (in millions):

Cash and cash equivalents			$	2,169
Credit facilities, maturing 2026 and 2028			2,900
Less:
Short-term debt			—
Net credit facilities			2,900
Total net liquidity			$	5,069

Refer to "Credit Facilities and Letters of Credit" below for further discussion regarding PacifiCorp's credit facilities.

Operating Activities

Net cash flows from operating activities for the three-month periods ended March 31, 2026 and 2025 were $(63) million and $488 million, respectively. The decrease is primarily due to higher cash paid for wildfire settlement payments, lower insurance reimbursements related to wildfires and higher operating expenses, partially offset by higher collections from retail customers.

The timing of PacifiCorp's income tax cash flows from period to period can be significantly affected by the estimated federal income tax payment methods selected and assumptions made for each payment date.

Investing Activities

Net cash flows from investing activities for the three-month periods ended March 31, 2026 and 2025 were $(712) million and $(683) million, respectively. The change is primarily due to an increase in capital expenditures of $29 million. Refer to "Future Uses of Cash" for discussion of capital expenditures.

Financing Activities

Net cash flows from financing activities for the three-month period ended March 31, 2026, were $2.9 billion. Sources of cash consisted of net proceeds from the issuance of senior secured debt of $2.9 billion and junior subordinated notes of $1.1 billion. Uses of cash consisted primarily of $1.0 billion for the net repayment of short-term debt and $100 million for the repayment of long-term debt.

For a discussion of recent financing transactions, refer to Note 6 of Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q.

Net cash flows from financing activities for the three-month period ended March 31, 2025, were $598 million. Sources of cash consisted of net proceeds from the issuance of junior subordinated debt of $842 million. Uses of cash consisted primarily of $240 million for the repayment of short-term debt.

72

---

Debt Restrictions

During the first quarter of 2026, certain state regulatory orders that authorized BHE's acquisition of PacifiCorp were modified for a limited term to indirectly limit PacifiCorp's capital structure by requiring the consolidated equity of PPW Holdings LLC as a percentage of total consolidated PPW Holdings LLC capitalization, excluding short-term debt and current maturities of long-term debt, to be no less than 40.00% for the Washington and Wyoming commitments and no less than 35.00% for the Oregon, Idaho and California commitments. The modifications will be in place for three years with options to extend. As of March 31, 2026, consolidated PPW Holdings LLC equity exceeded these thresholds.

Short-term Debt

Regulatory authorities limit PacifiCorp to $3.0 billion of short-term debt. As of March 31, 2026, PacifiCorp had no short-term debt outstanding. As of December 31, 2025, PacifiCorp had $1.0 billion of short-term debt outstanding at a weighted average rate of 5.23%.

Long-term Debt Authorizations

PacifiCorp currently has regulatory authority from the OPUC and the IPUC to issue an additional $150 million of long-term debt. PacifiCorp's authorization from the IPUC is through April 2029. PacifiCorp must make a notice filing with the WUTC prior to any future issuance. PacifiCorp currently has an effective shelf registration statement filed with the SEC to issue an indeterminate amount of first mortgage bonds and unsecured debt securities through July 2027.

Credit Facilities and Letters of Credit

As of March 31, 2026, PacifiCorp's $255 million letter of credit capacity under its $2.0 billion revolving credit facility was fully available.

As of March 31, 2026, PacifiCorp's $900 million 364‑day unsecured credit facility was fully available.

In April 2026, PacifiCorp entered into a letter of credit agreement under which letters of credit will be made available solely to provide collateral support for surety bonds issued pursuant to a corresponding surety arrangement for supersedeas undertakings to secure the performance and stay enforcement of trial court judgments entered against PacifiCorp relating to the James case. Refer to Note 6 of Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q for additional information regarding this arrangement.

Future Uses of Cash

PacifiCorp has available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, the issuance of commercial paper, the use of unsecured revolving credit facilities, bank loans, capital contributions and other sources. These sources are expected to provide funds required for current operations, capital expenditures, debt retirements and other capital requirements. The availability and terms under which PacifiCorp has access to external financing depend on a variety of factors, including PacifiCorp's credit ratings, investors' judgment of risk associated with PacifiCorp and conditions in the overall capital markets, including the condition of the utility industry.

Capital Expenditures

Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, impacts to customer rates; changes in environmental and other rules and regulations; outcomes of regulatory proceedings, including regulatory filings for Certificates of Public Convenience and Necessity; outcomes of legal actions associated with the Wildfires, including the James case; changes in income tax laws; general business conditions; new customer requests; load projections; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital.

73

---

PacifiCorp's historical and forecast capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items, are as follows (in millions):

			Three-Month Periods												Annual
			Ended March 31,												Forecast
			2025						2026						2026
Electric transmission			$	125					$	161					$	938
Electric distribution			198						178						848
Wildfire prevention			170						138						486
Wind generation			10						6						29
Other			185						234						490
Total			$	688					$	717					$	2,791

PacifiCorp's historical and forecast capital expenditures include the following:

•Electric transmission includes both growth projects and operating expenditures. Transmission growth primarily reflects costs associated with major transmission projects totaling $85 million and $49 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for major transmission projects that are expected to be placed in‑service through 2032 totals $335 million for the remainder of 2026.

•Electric distribution includes both growth projects and operating expenditures. Growth expenditures include spending on new customer connections totaling $93 million and $83 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for new customer connections totals $367 million for the remainder of 2026. The remaining investments primarily relate to expenditures for distribution operations.

•Wildfire prevention includes operating expenditures totaling $138 million and $170 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for wildfire prevention totals $348 million for the remainder of 2026.

•Other includes both growth projects and operating expenditures. Expenditures for information technology totaled $26 million and $41 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned information technology spending totals $85 million for the remainder of 2026. The remaining investments relate to operating projects that consist of routine expenditures for generation and other infrastructure needed to serve existing and expected demand.

Energy Supply Planning

As required by certain state regulations, PacifiCorp uses an IRP to develop a long-term resource plan to ensure that PacifiCorp can continue to provide reliable and cost-effective electric service to its customers while maintaining compliance with existing and evolving environmental laws and regulations. PacifiCorp files its IRP biennially with the state commissions in each of the six states where PacifiCorp operates. Five states indicate whether the IRP meets the state commission's IRP standards and guidelines, a process referred to as "acknowledgment" in some states. Acknowledgment by a state commission does not address cost recovery or prudency of resources ultimately selected.

In March 2025, PacifiCorp filed its 2025 IRP in Utah, Oregon, Wyoming, Washington, Idaho and California. The 2025 IRP highlights a need for investment in transmission infrastructure, renewable solar and wind resources, new energy storage, conversion of coal-fueled generating units to natural gas, demand response and energy efficiency programs and carbon capture technology. In December 2025, the IPUC acknowledged the 2025 IRP. In March 2026, PacifiCorp filed its 2025 IRP Update in all states.

Requests for Proposals

PacifiCorp issues individual RFPs to procure resources identified in the IRP or resources driven by customer demands and regulatory policy changes. The IRP and the RFPs provide for the identification and staged procurement of resources to meet load or state-specific compliance obligations. Depending upon the specific RFP, applicable laws and regulations may require PacifiCorp to file draft RFPs with the UPSC, the OPUC and the WUTC. Approval by the UPSC, the OPUC or the WUTC may be required depending on the nature of the RFPs.

74

---

Material Cash Requirements

As of March 31, 2026, there have been no material changes in cash requirements from the information provided in Item 7 of PacifiCorp's Annual Report on Form 10-K for the year ended December 31, 2025, other than those disclosed in Notes 6 and 11 of the Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q.

Regulatory Matters

PacifiCorp is subject to comprehensive regulation. Refer to "Regulatory Matters" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for discussion regarding PacifiCorp's current regulatory matters.

Environmental Laws and Regulations

PacifiCorp is subject to federal, state and local laws and regulations regarding air quality, climate change, emissions performance standards, water quality, coal ash disposal and other environmental matters that have the potential to impact PacifiCorp's current and future operations. In addition to imposing continuing compliance obligations, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. These laws and regulations are administered by various federal, state and local agencies. PacifiCorp believes it is in material compliance with all applicable laws and regulations, although many are subject to interpretation that may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and PacifiCorp is unable to predict the impact of the changing laws and regulations on its operations and financial results.

Refer to "Environmental Laws and Regulations" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for additional information regarding environmental laws and regulations.

Collateral and Contingent Features

Debt securities of PacifiCorp are rated by credit rating agencies. Assigned credit ratings are based on each rating agency's assessment of PacifiCorp's ability to, in general, meet the obligations of its issued debt securities. The credit ratings are not a recommendation to buy, sell or hold securities, and there is no assurance that a particular credit rating will continue for any given period of time. As of March 31, 2026, PacifiCorp's issuer credit ratings for senior unsecured debt from the recognized credit rating agencies were investment grade.

PacifiCorp has no credit rating downgrade triggers that would accelerate the maturity dates of outstanding debt and a change in ratings is not an event of default under the applicable debt instruments. PacifiCorp's unsecured revolving credit facilities do not require the maintenance of a minimum credit rating level to draw upon their availability. However, commitment fees and interest rates under the credit facilities are tied to credit ratings and increase or decrease when the ratings change. A ratings downgrade could also increase the future cost of commercial paper, short- and long-term debt issuances or new credit facilities. Certain authorizations or exemptions by regulatory commissions for the issuance of securities are valid as long as PacifiCorp maintains investment grade ratings on senior secured debt. A downgrade below that level would necessitate new regulatory applications and approvals.

In accordance with industry practice, certain wholesale energy agreements, including contracts for purchases, sales and transportation of electricity, natural gas, and coal, some of which are accounted for as derivatives, contain credit support provisions that in part base certain collateral requirements on credit ratings for senior unsecured debt as reported by one or more of the recognized credit rating agencies. These agreements may provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels ("credit-risk-related contingent features"). These agreements and other agreements that do not refer to specified rating-dependent thresholds may provide the right for counterparties to demand "adequate assurance" if there is a material adverse change in PacifiCorp's creditworthiness. These rights can vary by contract and by counterparty. If all credit-risk-related contingent features or adequate assurance provisions for these agreements had been triggered as of March 31, 2026, PacifiCorp would have been required to post $172 million of additional collateral. PacifiCorp's collateral requirements associated with wholesale energy agreements could fluctuate considerably due to market price volatility; changes in credit ratings; changes in legislation or regulation or other factors; and if counterparties demand adequate assurance in the event of a material adverse change in PacifiCorp's creditworthiness. Refer to Note 9 of Notes to Consolidated Financial Statements in Item 1 of this Form 10-Q for a discussion of PacifiCorp's collateral requirements specific to PacifiCorp's derivative contracts.

75

---

As described in Note 11 to the Consolidated Financial Statements in Item 1 of this Form 10-Q, PacifiCorp had posted surety bonds totaling $719 million as of March 31, 2026, to stay payment of damages in the James case pending appeals. A limited number of the surety bond agreements include contingent features associated with PacifiCorp's financial condition. If all financial condition-related contingent features associated with the surety bonds had been triggered as of March 31, 2026, PacifiCorp would have been required to post $135 million of cash collateral.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Consolidated Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, pension and other postretirement benefits, income taxes and wildfire loss contingencies. For additional discussion of PacifiCorp's critical accounting estimates, see Item 7 of PacifiCorp's Annual Report on Form 10-K for the year ended December 31, 2025. There have been no significant changes in PacifiCorp's assumptions regarding critical accounting estimates since December 31, 2025. Refer to Note 11 of the Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q for discussion of loss contingencies related to the Wildfires.

76

---

MidAmerican Funding, LLC and its subsidiaries and MidAmerican Energy Company

Consolidated Financial Section

77

---

PART I

Item 1.Financial Statements

Report of Independent Registered Public Accounting Firm						79
Balance Sheets						80
Statements of Operations						82
Statements of Changes in Shareholder's Equity						83
Statements of Cash Flows						84
Notes to Consolidated Financial Statements
General						85
New Accounting Pronouncements						85
Cash and Cash Equivalents and Restricted Cash and Cash Equivalents						86
Property, Plant and Equipment, Net						86
Income Taxes						87
Employee Benefit Plans						87
Fair Value Measurements						88
Commitments and Contingencies						90
Revenue from Contracts with Customers						91
Segment Information						92

78

---

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

MidAmerican Energy Company

Results of Review of Interim Financial Information

We have reviewed the accompanying balance sheet of MidAmerican Energy Company ("MidAmerican Energy") as of March 31, 2026, the related statements of operations, changes in shareholder's equity, and cash flows for the three-month periods ended March 31, 2026 and 2025, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the balance sheet of MidAmerican Energy as of December 31, 2025, and the related statements of operations, changes in shareholder's equity, and cash flows for the year then ended (not presented herein); and in our report dated February 27, 2026, we expressed an unqualified opinion on those financial statements. In our opinion, the information set forth in the accompanying balance sheet as of December 31, 2025, is fairly stated, in all material respects, in relation to the balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of MidAmerican Energy's management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to MidAmerican Energy in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/ Deloitte & Touche LLP

Des Moines, Iowa

May 1, 2026

79

---

MIDAMERICAN ENERGY COMPANY

BALANCE SHEETS (Unaudited)

(Amounts in millions)

			As of
			March 31,						December 31,
			2026						2025
ASSETS
Current assets:
Cash and cash equivalents			$	529					$	670
Trade receivables, net			499						453
Income tax receivable			315						82
Inventories			323						334
Prepayments			160						119
Other current assets			49						63
Total current assets			1,875						1,721
Property, plant and equipment, net			24,099						24,056
Regulatory assets			284						304
Investments and restricted investments			1,241						1,274
Other assets			288						288
Total assets			$	27,787					$	27,643

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

80

---

MIDAMERICAN ENERGY COMPANY

BALANCE SHEETS (Unaudited) (continued)

(Amounts in millions)

			As of
			March 31,						December 31,
			2026						2025
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities:
Accounts payable			$	390					$	505
Accrued interest			101						120
Accrued property, income and other taxes			186						198
Current portion of long-term debt			4						4
Other current liabilities			86						96
Total current liabilities			767						923
Long-term debt			9,204						9,203
Regulatory liabilities			1,260						1,323
Deferred income taxes			3,789						3,760
Asset retirement obligations			879						870
Other long-term liabilities			898						822
Total liabilities			16,797						16,901
Commitments and contingencies (Note 8)
Shareholder's equity:
Common stock - 350 shares authorized, no par value, 71 shares issued and outstanding			—						—
Additional paid-in capital			561						561
Retained earnings			10,429						10,181
Total shareholder's equity			10,990						10,742
Total liabilities and shareholder's equity			$	27,787					$	27,643

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

81

---

MIDAMERICAN ENERGY COMPANY

STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

									Three-Month Periods
									Ended March 31,
															2026						2025
Operating revenue:
Regulated electric															$	747					$	667
Regulated natural gas and other															393						347
Total operating revenue															1,140						1,014
Operating expenses:
Cost of fuel and energy															194						124
Cost of natural gas purchased for resale and other															290						245
Operations and maintenance															220						227
Depreciation and amortization															277						307
Property and other taxes															48						44
Total operating expenses															1,029						947
Operating income															111						67
Other income (expense):
Interest expense															(105)						(101)
Allowance for borrowed funds															6						7
Allowance for equity funds															17						18
Other, net															3						5
Total other income (expense)															(79)						(71)
Income (loss) before income tax expense (benefit)															32						(4)
Income tax expense (benefit)															(216)						(236)
Net income															$	248					$	232

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

82

---

MIDAMERICAN ENERGY COMPANY

STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY (Unaudited)

(Amounts in millions)

			Common Stock						Additional Paid-in Capital						Retained Earnings						Total Shareholder's Equity
Balance, December 31, 2024			$	—					$	561					$	9,620					$	10,181
Net income			—						—						232						232
Other equity transactions			—						—						(1)						(1)
Balance, March 31, 2025			$	—					$	561					$	9,851					$	10,412
Balance, December 31, 2025			$	—					$	561					$	10,181					$	10,742
Net income			—						—						248						248
Balance, March 31, 2026			$	—					$	561					$	10,429					$	10,990

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

83

---

MIDAMERICAN ENERGY COMPANY

STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Cash flows from operating activities:
Net income			$	248					$	232
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization			277						307
Amortization of utility plant to other operating expenses			11						8
Allowance for equity funds			(17)						(18)
Deferred income taxes and investment tax credits, net			22						(12)
Other, net			12						48
Changes in other operating assets and liabilities:
Trade receivables and other assets			(71)						(99)
Inventories			11						59
Accrued property, income and other taxes, net			(246)						(251)
Accounts payable and other liabilities			(65)						(6)
Net cash flows from operating activities			182						268
Cash flows from investing activities:
Capital expenditures			(418)						(405)
Purchases of marketable securities			(144)						(84)
Proceeds from sales of marketable securities			151						86
Other, net			—						2
Net cash flows from investing activities			(411)						(401)
Cash flows from financing activities:
Repayments of long-term debt			(1)						(14)
Other, net			88						—
Net cash flows from financing activities			87						(14)
Net change in cash and cash equivalents and restricted cash and cash equivalents			(142)						(147)
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period			676						555
Cash and cash equivalents and restricted cash and cash equivalents at end of period			$	534					$	408

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

84

---

MIDAMERICAN ENERGY COMPANY

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

(1)    General

MidAmerican Energy Company ("MidAmerican Energy") is a public utility with electric and natural gas operations and is the principal subsidiary of MHC Inc. ("MHC"). MHC is a holding company that conducts no business other than the ownership of its subsidiaries. MHC's nonregulated subsidiary is Midwest Capital Group, Inc. MHC is the direct wholly owned subsidiary of MidAmerican Funding, LLC ("MidAmerican Funding"), which is an Iowa limited liability company with Berkshire Hathaway Energy Company ("BHE") as its sole member. BHE is a holding company headquartered in Iowa, that has investments in subsidiaries principally engaged in energy businesses. BHE is a wholly owned subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The accompanying Financial Statements and Notes to Financial Statements should be read in conjunction with MidAmerican Energy's Annual Report on Form 10-K for the year ended December 31, 2025. The unaudited Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Financial Statements as of March 31, 2026, and for the three-month periods ended March 31, 2026 and 2025. The results of operations for the three-month period ended March 31, 2026, are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Financial Statements. Note 2 of Notes to Financial Statements included in MidAmerican Energy's Annual Report on Form 10-K for the year ended December 31, 2025, describes the most significant accounting policies used in the preparation of the unaudited Financial Statements. There have been no significant changes in MidAmerican Energy's accounting policies or its assumptions regarding significant accounting estimates during the three-month period ended March 31, 2026.

(2)    New Accounting Pronouncements

In November 2024, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures Subtopic 220-40, "Disaggregation of Income Statement Expenses" which addresses requests from investors for more detailed information about certain expenses and requires disclosure of the amounts of purchases of inventory, employee compensation, depreciation and intangible asset amortization included in each relevant expense caption presented on the income statement. This guidance, as clarified in ASU 2025-01, is effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. Early adoption is permitted and should be applied on a prospective basis, however retrospective application is permitted. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements.

85

---

(3)    Cash and Cash Equivalents and Restricted Cash and Cash Equivalents

Cash equivalents consist of funds invested in money market mutual funds, U.S. Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted cash and cash equivalents consist substantially of funds restricted for wildlife preservation. A reconciliation of cash and cash equivalents and restricted cash and cash equivalents as presented on the Statements of Cash Flows is outlined below and disaggregated by the line items in which they appear on the Balance Sheets (in millions):

			As of
			March 31,						December 31,
			2026						2025
Cash and cash equivalents			$	529					$	670
Restricted cash and cash equivalents in other current assets			5						6
Total cash and cash equivalents and restricted cash and cash equivalents			$	534					$	676

(4)    Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

									As of
									March 31,						December 31,
			Depreciable Life						2026						2025
Utility plant:
Generation			20-62 years						$	18,677					$	18,804
Transmission			55-80 years						3,310						3,297
Electric distribution			15-80 years						6,395						6,326
Natural gas distribution			30-75 years						2,615						2,600
Utility plant in-service									30,997						31,027
Accumulated depreciation and amortization									(8,410)						(8,304)
Utility plant in-service, net									22,587						22,723
Nonregulated, net of accumulated depreciation and amortization			20-50 years						10						10
									22,597						22,733
Construction work-in-progress									1,502						1,323
Property, plant and equipment, net									$	24,099					$	24,056

Under a revenue sharing arrangement in Iowa, MidAmerican Energy accrues throughout the year a regulatory liability based on the extent to which its anticipated annual equity return exceeds specified thresholds, with an equal amount recorded in depreciation and amortization expense. The annual regulatory liability accrual reduces utility plant upon final determination of the amount. For the three-month periods ended March 31, 2026 and 2025, $10 million and $61 million, respectively, is reflected in depreciation and amortization expense on the Statements of Operations.

86

---

(5)    Income Taxes

Berkshire Hathaway includes BHE and subsidiaries in its U.S. federal income tax return and BHE includes its subsidiaries in certain state income tax returns. Consistent with established regulatory practice, MidAmerican Energy's provision for income tax has been computed on a stand-alone basis, and substantially all of its currently payable or receivable income tax is remitted to or received from BHE pursuant to a tax allocation agreement. For current federal and state income taxes, MidAmerican Energy had a net receivable from BHE of $315 million and $79 million as of March 31, 2026 and December 31, 2025, respectively. MidAmerican Energy received no net cash payments for income tax from BHE for each of the three-month periods ended March 31, 2026 and 2025.

The effective income tax rate for the three-month period ended March 31, 2025, of 5,900.0% resulted from a $236 million income tax benefit from energy-related tax credits associated with a $4 million pre-tax loss.

A reconciliation of the federal statutory income tax rate to MidAmerican Energy's effective income tax rate applicable to income (loss) before income tax expense (benefit) is as follows (amounts in millions):

									Three-Month Periods
									Ended March 31,
															2026												2025
																											Amount						Percent						Amount						Percent
U.S. federal statutory income tax rate																											$	7					21.0		%				$	(1)					21.0		%
State income tax, net of federal income tax																											(1)						(2.5)						—						—
Energy-related tax credits																											(222)						(693.8)						(236)						5,900.0
Other adjustments:
Effects of ratemaking																											—						—						1						(21.0)
Effective income tax rate																											$	(216)					(675.3)		%				$	(236)					5,900.0		%

Energy-related tax credits relate primarily to production tax credits ("PTC") earned by MidAmerican Energy's wind- and solar-powered generating facilities. Federal renewable electricity PTCs are earned as energy from qualifying wind- and solar-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. MidAmerican Energy recognizes its renewable electricity PTCs throughout the year based on when the credits are earned and excludes them from the annual effective tax rate that is the basis for the interim recognition of the remaining income tax expense. Wind- and solar-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in-service.

(6)    Employee Benefit Plans

MidAmerican Energy sponsors a noncontributory defined benefit pension plan covering a majority of all employees of BHE and its domestic energy subsidiaries other than PacifiCorp and NV Energy, Inc. MidAmerican Energy also sponsors certain postretirement healthcare and life insurance benefits covering substantially all retired employees of BHE and its domestic energy subsidiaries other than PacifiCorp and NV Energy, Inc.

87

---

Net periodic benefit cost (credit) for the plans of MidAmerican Energy and the aforementioned affiliates included the following components (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Pension:
Service cost															$	2					$	2
Interest cost															7						8
Expected return on plan assets															(8)						(8)
Net periodic benefit cost															$	1					$	2
Other postretirement:
Service cost															$	1					$	1
Interest cost															3						3
Expected return on plan assets															(5)						(5)
Net periodic benefit credit															$	(1)					$	(1)

Amounts other than the service cost for pension and other postretirement benefit plans are recorded in other, net on the Statements of Operations. Employer contributions to the pension and other postretirement benefit plans during 2026 are expected to be $7 million and $1 million, respectively. As of March 31, 2026, $2 million and $— million of contributions had been made to the pension and other postretirement benefit plans, respectively.

(7)    Fair Value Measurements

The carrying value of MidAmerican Energy's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. MidAmerican Energy has various financial assets and liabilities that are measured at fair value on the Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

•Level 1 — Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that MidAmerican Energy has the ability to access at the measurement date.

•Level 2 — Inputs include 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 that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).

•Level 3 — Unobservable inputs reflect MidAmerican Energy's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. MidAmerican Energy develops these inputs based on the best information available, including its own data.

88

---

The following table presents MidAmerican Energy's financial assets and liabilities recognized on the Balance Sheets and measured at fair value on a recurring basis (in millions):

			Input Levels for Fair Value Measurements
			Level 1						Level 2						Level 3						Other(1)						Total
As of March 31, 2026:
Assets:
Commodity derivatives			$	1					$	1					$	—					$	(1)					$	1
Money market mutual funds			439						—						—						—						439
Debt securities:
U.S. government obligations			287						—						—						—						287
Corporate obligations			—						127						—						—						127
Municipal obligations			—						2						—						—						2
Equity securities:
U.S. companies			522						—						—						—						522
International companies			9						—						—						—						9
Investment funds			13						—						—						—						13
			$	1,271					$	130					$	—					$	(1)					$	1,400
Liabilities:
Commodity derivatives			$	—					$	(8)					$	(1)					$	2					$	(7)

			Input Levels for Fair Value Measurements
			Level 1						Level 2						Level 3						Other(1)						Total
As of December 31, 2025:
Assets:
Commodity derivatives			$	—					$	3					$	1					$	(2)					$	2
Money market mutual funds			622						—						—						—						622
Debt securities:
U.S. government obligations			284						—						—						—						284
Corporate obligations			—						133						—						—						133
Municipal obligations			—						2						—						—						2
Equity securities:
U.S. companies			548						—						—						—						548
International companies			9						—						—						—						9
Investment funds			20						—						—						—						20
			$	1,483					$	138					$	1					$	(2)					$	1,620
Liabilities:
Commodity derivatives			$	—					$	(18)					$	(3)					$	7					$	(14)

(1)Represents netting under master netting arrangements and a net cash collateral receivable of $1 million and $5 million as of March 31, 2026, and December 31, 2025, respectively.

MidAmerican Energy's investments in money market mutual funds and debt and equity securities are stated at fair value, with debt securities accounted for as available-for-sale securities. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. In the absence of a quoted market price or net asset value of an identical security, the fair value is determined using pricing models or net asset values based on observable market inputs and quoted market prices of securities with similar characteristics.

89

---

The following table reconciles the beginning and ending balances of MidAmerican Energy's commodity derivative assets and liabilities measured at fair value on a recurring basis using significant Level 3 inputs (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Beginning balance															$	(2)					$	(2)
Changes in fair value recognized in net regulatory assets															(1)						1
Settlements															2						2
Ending balance															$	(1)					$	1

MidAmerican Energy's long-term debt is carried at cost on the Balance Sheets. The fair value of MidAmerican Energy's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of MidAmerican Energy's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of MidAmerican Energy's long-term debt (in millions):

			As of March 31, 2026												As of December 31, 2025
			Carrying Value						Fair Value						Carrying Value						Fair Value
Long-term debt			$	9,208					$	8,270					$	9,207					$	8,416

(8)    Commitments and Contingencies

Commitments

MidAmerican Energy has the following firm commitments that are not reflected on the Balance Sheets.

Construction Commitments

During the three-month period ended March 31, 2026, MidAmerican Energy entered into firm construction commitments totaling $393 million for the remainder of 2026 through 2029 related to the construction of wind-powered, solar-powered and natural gas-powered generating facilities in Iowa.

Environmental Laws and Regulations

MidAmerican Energy is subject to federal, state and local laws and regulations regarding air quality, climate change, emissions performance standards, water quality, coal ash disposal and other environmental matters that have the potential to impact its current and future operations. MidAmerican Energy believes it is in material compliance with all applicable laws and regulations.

Legal Matters

MidAmerican Energy is party to a variety of legal actions arising out of the normal course of business. MidAmerican Energy does not believe that such normal and routine litigation will have a material impact on its financial results.

90

---

(9)    Revenue from Contracts with Customers

The following table summarizes MidAmerican Energy's revenue from contracts with customers ("Customer Revenue") by line of business, with further disaggregation of retail by customer class, including a reconciliation to MidAmerican Energy's reportable segment information included in Note 10 (in millions):

									For the Three-Month Period Ended March 31, 2026
																											Electric						Natural Gas						Other						Total
Customer Revenue:
Retail:
Residential																											$	181					$	217					$	—					$	398
Commercial																											82						88						—						170
Industrial																											293						9						—						302
Natural gas transportation services																											—						16						—						16
Other retail																											33						2						—						35
Total retail																											589						332						—						921
Wholesale																											128						58						—						186
Multi-value transmission projects																											13						—						—						13
Other Customer Revenue																											—						—						3						3
Total Customer Revenue																											730						390						3						1,123
Other revenue																											17						—						—						17
Total operating revenue																											$	747					$	390					$	3					$	1,140

									For the Three-Month Period Ended March 31, 2025
																											Electric						Natural Gas						Other						Total
Customer Revenue:
Retail:
Residential																											$	181					$	202					$	—					$	383
Commercial																											80						80						—						160
Industrial																											251						9						—						260
Natural gas transportation services																											—						16						—						16
Other retail																											33						2						—						35
Total retail																											545						309						—						854
Wholesale																											80						36						—						116
Multi-value transmission projects																											14						—						—						14
Other Customer Revenue																											—						—						2						2
Total Customer Revenue																											639						345						2						986
Other revenue																											28						—						—						28
Total operating revenue																											$	667					$	345					$	2					$	1,014

91

---

(10)    Segment Information

MidAmerican Energy's chief operating decision maker ("CODM") is its President and Chief Executive Officer. Net income for each reportable segment is considered by the CODM in allocating resources and capital. When making decisions about the allocation of resources and capital to each reportable segment, the CODM generally considers actual results versus historical results, budgets or forecasts, as well as unique risks and opportunities.

MidAmerican Energy has identified two reportable operating segments: regulated electric and regulated natural gas. The regulated electric segment derives most of its revenue from regulated retail sales of electricity to residential, commercial, and industrial customers and from wholesale sales. The regulated natural gas segment derives most of its revenue from regulated retail sales of natural gas to residential, commercial, and industrial customers and also obtains revenue by transporting natural gas owned by others through its distribution system. Pricing for regulated electric and regulated natural gas sales are established separately by regulatory agencies; therefore, management also reviews each segment separately to make decisions regarding allocation of resources and in evaluating performance. Common operating costs are allocated to each segment based on certain factors, which primarily relate to the nature of the cost.

The following tables provide information on a reportable segment basis (in millions):

			For the Three-Month Period Ended March 31, 2026
			Electric						Natural Gas						Other(1)						Total
Operating revenue			$	747					$	390					$	3					$	1,140
Cost of sales			194						290						—						484
Operations and maintenance			181						39						—						220
Depreciation and amortization			259						18						—						277
Property and other taxes			43						5						—						48
Operating income			70						38						3						111
Interest expense			(96)						(9)						—						(105)
Interest and dividend income			5						1						—						6
Income tax expense (benefit)			(224)						7						1						(216)
Other segment items(2)			23						(3)						—						20
Net income (loss)			$	226					$	20					$	2					$	248
Capital expenditures			$	394					$	24					$	—					$	418

			For the Three-Month Period Ended March 31, 2025
			Electric						Natural Gas						Other(1)						Total
Operating revenue			$	667					$	345					$	2					$	1,014
Cost of sales			124						245						—						369
Operations and maintenance			193						33						1						227
Depreciation and amortization			290						17						—						307
Property and other taxes			40						4						—						44
Operating income			20						46						1						67
Interest expense			(93)						(8)						—						(101)
Interest and dividend income			6						1						—						7
Income tax expense (benefit)			(246)						10						—						(236)
Other segment items(2)			23						1						(1)						23
Net income			$	202					$	30					$	—					$	232
Capital expenditures			$	374					$	31					$	—					$	405

92

---

			As of
			March 31,						December 31,
			2026						2025
Assets:
Regulated electric			$	25,692					$	25,495
Regulated natural gas			2,092						2,145
Other(1)			3						3
Total assets			$	27,787					$	27,643

(1)The differences between the reportable segment amounts and the consolidated amounts, described as Other, relate to nonregulated activities of MidAmerican Energy.

(2)Other segment items include allowance for borrowed and equity funds, gains (losses) on marketable securities and other income (expense).

93

---

PART I

Item 1.Financial Statements

Report of Independent Registered Public Accounting Firm						95
Consolidated Balance Sheets						96
Consolidated Statements of Operations						98
Consolidated Statements of Changes in Member's Equity						99
Consolidated Statements of Cash Flows						100
Notes to Consolidated Financial Statements
General						101
New Accounting Pronouncements						101
Cash and Cash Equivalents and Restricted Cash and Cash Equivalents						101
Property, Plant and Equipment, Net						102
Income Taxes						102
Employee Benefit Plans						102
Fair Value Measurements						103
Commitments and Contingencies						103
Revenue from Contracts with Customers						103
Segment Information						103

94

---

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Managers and Member of

MidAmerican Funding, LLC

Results of Review of Interim Financial Information

We have reviewed the accompanying consolidated balance sheet of MidAmerican Funding, LLC and subsidiaries ("MidAmerican Funding") as of March 31, 2026, the related consolidated statements of operations, changes in member's equity, and cash flows for the three-month periods ended March 31, 2026 and 2025, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB) and in accordance with auditing standards generally accepted in the United States of America, the consolidated balance sheet of MidAmerican Funding as of December 31, 2025, and the related consolidated statements of operations, changes in member's equity, and cash flows for the year then ended (not presented herein); and in our report dated February 27, 2026, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2025, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of MidAmerican Funding's management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to MidAmerican Funding in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with standards of the PCAOB and with auditing standards generally accepted in the United States of America applicable to reviews of interim financial information. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB and with auditing standards generally accepted in the United States of America, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/ Deloitte & Touche LLP

Des Moines, Iowa

May 1, 2026

95

---

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions)

			As of
			March 31,						December 31,
			2026						2025
ASSETS
Current assets:
Cash and cash equivalents			$	529					$	672
Trade receivables, net			499						453
Income tax receivable			316						82
Inventories			323						334
Prepayments			160						119
Other current assets			47						57
Total current assets			1,874						1,717
Property, plant and equipment, net			24,108						24,065
Goodwill			1,270						1,270
Regulatory assets			284						304
Investments and restricted investments			1,242						1,276
Other assets			288						286
Total assets			$	29,066					$	28,918

The accompanying notes are an integral part of these consolidated financial statements.

96

---

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited) (continued)

(Amounts in millions)

			As of
			March 31,						December 31,
			2026						2025
LIABILITIES AND MEMBER'S EQUITY
Current liabilities:
Accounts payable			$	388					$	498
Accrued interest			102						126
Accrued property, income and other taxes			186						198
Note payable to affiliate			13						7
Current portion of long-term debt			4						4
Other current liabilities			86						96
Total current liabilities			779						929
Long-term debt			9,444						9,443
Regulatory liabilities			1,260						1,323
Deferred income taxes			3,787						3,758
Asset retirement obligations			879						870
Other long-term liabilities			899						822
Total liabilities			17,048						17,145
Commitments and contingencies (Note 8)
Member's equity:
Paid-in capital			1,679						1,679
Retained earnings			10,339						10,094
Total member's equity			12,018						11,773
Total liabilities and member's equity			$	29,066					$	28,918

The accompanying notes are an integral part of these consolidated financial statements.

97

---

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

									Three-Month Periods
									Ended March 31,
															2026						2025
Operating revenue:
Regulated electric															$	747					$	667
Regulated natural gas and other															393						347
Total operating revenue															1,140						1,014
Operating expenses:
Cost of fuel and energy															194						124
Cost of natural gas purchased for resale and other															290						245
Operations and maintenance															220						227
Depreciation and amortization															277						307
Property and other taxes															48						44
Total operating expenses															1,029						947
Operating income															111						67
Other income (expense):
Interest expense															(109)						(105)
Allowance for borrowed funds															6						7
Allowance for equity funds															17						18
Other, net															2						5
Total other income (expense)															(84)						(75)
Income (loss) before income tax expense (benefit)															27						(8)
Income tax expense (benefit)															(218)						(236)
Net income															$	245					$	228

The accompanying notes are an integral part of these consolidated financial statements.

98

---

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY (Unaudited)

(Amounts in millions)

			Paid-in Capital						Retained Earnings						Total Member's Equity
Balance, December 31, 2024			$	1,679					$	9,520					$	11,199
Net income			—						228						228
Balance, March 31, 2025			$	1,679					$	9,748					$	11,427
Balance, December 31, 2025			$	1,679					$	10,094					$	11,773
Net income			—						245						245
Balance, March 31, 2026			$	1,679					$	10,339					$	12,018

The accompanying notes are an integral part of these consolidated financial statements.

99

---

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Cash flows from operating activities:
Net income			$	245					$	228
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization			277						307
Amortization of utility plant to other operating expenses			11						8
Allowance for equity funds			(17)						(18)
Deferred income taxes and investment tax credits, net			22						(12)
Other, net			12						48
Changes in other operating assets and liabilities:
Trade receivables and other assets			(75)						(99)
Inventories			11						59
Accrued property, income and other taxes, net			(248)						(252)
Accounts payable and other liabilities			(64)						(10)
Net cash flows from operating activities			174						259
Cash flows from investing activities:
Capital expenditures			(418)						(405)
Purchases of marketable securities			(144)						(84)
Proceeds from sales of marketable securities			151						86
Other, net			—						2
Net cash flows from investing activities			(411)						(401)
Cash flows from financing activities:
Repayments of long-term debt			(1)						(14)
Net change in note payable to affiliate			6						7
Other, net			88						—
Net cash flows from financing activities			93						(7)
Net change in cash and cash equivalents and restricted cash and cash equivalents			(144)						(149)
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period			678						558
Cash and cash equivalents and restricted cash and cash equivalents at end of period			$	534					$	409

The accompanying notes are an integral part of these consolidated financial statements.

100

---

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    General

MidAmerican Funding, LLC ("MidAmerican Funding") is an Iowa limited liability company with Berkshire Hathaway Energy Company ("BHE") as its sole member. BHE is a holding company headquartered in Iowa, that has investments in subsidiaries principally engaged in energy businesses. BHE is a wholly owned subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway"). MidAmerican Funding's direct wholly owned subsidiary is MHC Inc. ("MHC"), which constitutes substantially all of MidAmerican Funding's assets, liabilities and business activities except those related to MidAmerican Funding's long-term debt securities. MHC conducts no business other than the ownership of its subsidiaries. MHC's principal subsidiary is MidAmerican Energy Company ("MidAmerican Energy"), a public utility with electric and natural gas operations, and its direct wholly owned nonregulated subsidiary is Midwest Capital Group, Inc.

The accompanying Consolidated Financial Statements and Notes to Consolidated Financial Statements should be read in conjunction with MidAmerican Funding's Annual Report on Form 10-K for the year ended December 31, 2025. The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2026, and for the three-month periods ended March 31, 2026 and 2025. The results of operations for the three-month period ended March 31, 2026, are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in MidAmerican Funding's Annual Report on Form 10-K for the year ended December 31, 2025, describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in MidAmerican Funding's accounting policies or its assumptions regarding significant accounting estimates during the three-month period ended March 31, 2026.

(2)    New Accounting Pronouncements

Refer to Note 2 of MidAmerican Energy's Notes to Financial Statements.

(3)    Cash and Cash Equivalents and Restricted Cash and Cash Equivalents

Cash equivalents consist of funds invested in money market mutual funds, U.S. Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted cash and cash equivalents consist substantially of funds restricted for wildlife preservation. A reconciliation of cash and cash equivalents and restricted cash and cash equivalents as presented on the Consolidated Statements of Cash Flows is outlined below and disaggregated by the line items in which they appear on the Consolidated Balance Sheets (in millions):

			As of
			March 31,						December 31,
			2026						2025
Cash and cash equivalents			$	529					$	672
Restricted cash and cash equivalents in other current assets			5						6
Total cash and cash equivalents and restricted cash and cash equivalents			$	534					$	678

101

---

(4)    Property, Plant and Equipment, Net

Refer to Note 4 of MidAmerican Energy's Notes to Financial Statements. In addition to MidAmerican Energy's property, plant and equipment, net, MidAmerican Funding had nonregulated property, plant and equipment, net, of $9 million as of March 31, 2026 and December 31, 2025.

(5)    Income Taxes

Berkshire Hathaway includes BHE and subsidiaries in its U.S. federal income tax return and BHE includes its subsidiaries in certain state income tax returns. Consistent with established regulatory practice, MidAmerican Funding's provisions for income tax has been computed on a stand-alone basis and substantially all of its currently payable or receivable income tax is remitted to or received from BHE pursuant to a tax allocation agreement. For current federal and state income taxes, MidAmerican Funding had a net receivable from BHE of $316 million and $79 million as of March 31, 2026 and December 31, 2025, respectively. MidAmerican Funding received no net cash payments for income tax from BHE for each of the three-month periods ended March 31, 2026 and 2025.

The effective income tax rate for the three-month period ended March 31, 2025, of 2,950.0% resulted from a $236 million income tax benefit from energy-related tax credits associated with an $8 million pre-tax loss.

A reconciliation of the federal statutory income tax rate to MidAmerican Funding's effective income tax rate applicable to income (loss) before income tax expense (benefit) is as follows (amounts in millions):

									Three-Month Periods
									Ended March 31,
															2026												2025
																											Amount						Percent						Amount						Percent
U.S federal statutory income tax rate																											$	6					21.0		%				$	(2)					21.0		%
State income tax, net of federal income tax																											(1)						(3.7)						—						—
Energy-related tax credits																											(222)						(822.2)						(236)						2,950.0
Other adjustments:
Effects of ratemaking																											—						—						1						(12.5)
Other, net																											(1)						(2.5)						1						(8.5)
Effective income tax rate																											$	(218)					(807.4)		%				$	(236)					2,950.0		%

Energy-related tax credits relate primarily to production tax credits ("PTC") earned by MidAmerican Energy's wind- and solar-powered generating facilities. Federal renewable electricity PTCs are earned as energy from qualifying wind- and solar-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. MidAmerican Funding recognizes its renewable electricity PTCs throughout the year based on when the credits are earned and excludes them from the annual effective tax rate that is the basis for the interim recognition of the remaining income tax expense. Wind- and solar-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in-service.

(6)    Employee Benefit Plans

Refer to Note 6 of MidAmerican Energy's Notes to Financial Statements.

102

---

(7)    Fair Value Measurements

Refer to Note 7 of MidAmerican Energy's Notes to Financial Statements. MidAmerican Funding's long-term debt is carried at cost on the Consolidated Financial Statements. The fair value of MidAmerican Funding's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of MidAmerican Funding's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of MidAmerican Funding's long-term debt (in millions):

			As of March 31, 2026												As of December 31, 2025
			Carrying Value						Fair Value						Carrying Value						Fair Value
Long-term debt			$	9,448					$	8,524					$	9,447					$	8,672

(8)    Commitments and Contingencies

MidAmerican Funding is party to a variety of legal actions arising out of the normal course of business. MidAmerican Funding does not believe that such normal and routine litigation will have a material impact on its consolidated financial results.

Refer to Note 8 of MidAmerican Energy's Notes to Financial Statements.

(9)    Revenue from Contracts with Customers

Refer to Note 9 of MidAmerican Energy's Notes to Financial Statements.

(10)    Segment Information

MidAmerican Funding's chief operating decision maker ("CODM") is its President. Net income for each reportable segment is considered by the CODM in allocating resources and capital. When making decisions about the allocation of resources and capital to each reportable segment, the CODM generally considers actual results versus historical results, budgets or forecasts, as well as unique risks and opportunities.

MidAmerican Funding has identified two reportable operating segments: regulated electric and regulated natural gas. The regulated electric segment derives most of its revenue from regulated retail sales of electricity to residential, commercial, and industrial customers and from wholesale sales. The regulated natural gas segment derives most of its revenue from regulated retail sales of natural gas to residential, commercial, and industrial customers and also obtains revenue by transporting natural gas owned by others through its distribution system. Pricing for regulated electric and regulated natural gas sales are established separately by regulatory agencies; therefore, management also reviews each segment separately to make decisions regarding allocation of resources and in evaluating performance. Common operating costs are allocated to each segment based on certain factors, which primarily relate to the nature of the cost.

103

---

The following tables provide information on a reportable segment basis (in millions):

			For the Three-Month Period Ended March 31, 2026
			Electric						Natural Gas						Other(1)						Total
Operating revenue			$	747					$	390					$	3					$	1,140
Cost of sales			194						290						—						484
Operations and maintenance			181						39						—						220
Depreciation and amortization			259						18						—						277
Property and other taxes			43						5						—						48
Operating income (loss)			70						38						3						111
Interest expense			(96)						(9)						(4)						(109)
Interest and dividend income			5						1						—						6
Income tax expense (benefit)			(224)						7						(1)						(218)
Other segment items(2)			23						(3)						(1)						19
Net income (loss)			$	226					$	20					$	(1)					$	245
Capital expenditures			$	394					$	24					$	—					$	418

			For the Three-Month Period Ended March 31, 2025
			Electric						Natural Gas						Other(1)						Total
Operating revenue			$	667					$	345					$	2					$	1,014
Cost of sales			124						245						—						369
Operations and maintenance			193						33						1						227
Depreciation and amortization			290						17						—						307
Property and other taxes			40						4						—						44
Operating income			20						46						1						67
Interest expense			(93)						(8)						(4)						(105)
Interest and dividend income			6						1						—						7
Income tax expense (benefit)			(246)						10						—						(236)
Other segment items(2)			23						1						(1)						23
Net income (loss)			$	202					$	30					$	(4)					$	228
Capital expenditures			$	374					$	31					$	—					$	405

104

---

			As of
			March 31,						December 31,
			2026						2025
Assets:
Regulated electric			$	26,883					$	26,686
Regulated natural gas			2,171						2,224
Other(1)			12						8
Total assets			$	29,066					$	28,918
Goodwill:
Regulated electric			$	1,191					$	1,191
Regulated natural gas			79						79
Total goodwill			$	1,270					$	1,270

(1)The differences between the reportable segment amounts and the consolidated amounts, described as Other, consists of the nonregulated subsidiaries of MidAmerican Funding not engaged in the energy business.

(2)Other segment items include allowance for borrowed and equity funds, gains (losses) on marketable securities and other income (expense).

105

---

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

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of MidAmerican Funding and its subsidiaries and MidAmerican Energy during the periods included herein. Information in Management's Discussion and Analysis related to MidAmerican Energy, whether or not segregated, also relates to MidAmerican Funding. Information related to other subsidiaries of MidAmerican Funding pertains only to the discussion of the financial condition and results of operations of MidAmerican Funding. Where necessary, discussions have been segregated under the heading "MidAmerican Funding" to allow the reader to identify information applicable only to MidAmerican Funding. Explanations include management's best estimate of the impact of weather, customer growth, usage trends and other factors. This discussion should be read in conjunction with MidAmerican Funding's historical unaudited Consolidated Financial Statements and Notes to Consolidated Financial Statements and MidAmerican Energy's historical unaudited Financial Statements and Notes to Financial Statements in Part I, Item 1 of this Form 10-Q. MidAmerican Funding's and MidAmerican Energy's actual results in the future could differ significantly from the historical results.

Results of Operations for the First Quarter of 2026 and 2025

Overview

MidAmerican Energy -

MidAmerican Energy's net income for the first quarter of 2026 was $248 million, an increase of $16 million, or 7%, compared to 2025, primarily due to lower depreciation and amortization expense, higher electric utility margin and lower operations and maintenance expense, partially offset by a lower income tax benefit, higher interest expense and higher property and other tax expense. Electric utility margin increased primarily due to higher electric retail customer usage and favorable price impacts from changes in sales mix, partially offset by the unfavorable impact of weather, lower recoveries through bill riders and lower wholesale margin. Electric retail customer volumes increased 4% primarily due to higher customer usage for industrial customers. Lower renewable-powered generation from lower wind resulted in decreased wholesale volumes of 3% and increased coal-fueled generation and energy purchased volumes. Natural gas retail customer sales decreased 7% due to the unfavorable impact of weather.

MidAmerican Funding -

MidAmerican Funding's net income for the first quarter of 2026 was $245 million, an increase of $17 million, or 7%, compared to 2025. The variance in net income was primarily due to the changes in MidAmerican Energy's earnings discussed above.

Non-GAAP Financial Measure

Management utilizes various key financial measures that are prepared in accordance with GAAP, as well as non-GAAP financial measures such as electric utility margin and natural gas utility margin, to help evaluate results of operations. Electric utility margin is calculated as regulated electric operating revenue less cost of fuel and energy, which are captions presented on the Statements of Operations. Natural gas utility margin is calculated as regulated natural gas operating revenue less regulated cost of natural gas purchased for resale, which are included in regulated natural gas and other and cost of natural gas purchased for resale and other, respectively, on the Statements of Operations.

MidAmerican Energy's cost of fuel and energy and cost of natural gas purchased for resale are generally recovered from its retail customers through regulatory recovery mechanisms, and as a result, changes in MidAmerican Energy's expenses included in regulatory recovery mechanisms result in comparable changes to revenue. As such, management believes electric utility margin and natural gas utility margin more appropriately and concisely explain results of operations rather than a discussion of revenue and cost of sales separately. Management believes the presentation of electric utility margin and natural gas utility margin provides meaningful and valuable insight into the information management considers important to understanding the business and a measure of comparability to others in the industry.

106

---

Electric utility margin and natural gas utility margin are not measures calculated in accordance with GAAP and should be viewed as a supplement to, and not a substitute for, operating income, which is the most comparable financial measure prepared in accordance with GAAP. The following table provides a reconciliation of utility margin to MidAmerican Energy's operating income (in millions):

			First Quarter
			2026						2025						Change
Electric utility margin:
Operating revenue			$	747					$	667					$	80					12		%
Cost of fuel and energy			194						124						70						56
Electric utility margin			553						543						10						2		%
Natural gas utility margin:
Operating revenue			390						345						45						13		%
Natural gas purchased for resale			290						245						45						18
Natural gas utility margin			100						100						—						—		%
Utility margin			653						643						10						2		%
Other operating revenue			3						2						1						50		%
Operations and maintenance			220						227						(7)						(3)
Depreciation and amortization			277						307						(30)						(10)
Property and other taxes			48						44						4						9
Operating income			$	111					$	67					$	44					66		%

107

---

Electric Utility Margin

A comparison of key operating results related to electric utility margin is as follows:

			First Quarter
			2026						2025						Change
Utility margin (in millions):
Operating revenue			$	747					$	667					$	80					12		%
Cost of fuel and energy			194						124						70						56
Utility margin			$	553					$	543					$	10					2		%
Sales (GWhs):
Residential			1,846						1,904						(58)						(3)		%
Commercial			1,039						1,037						2						—
Industrial			5,082						4,642						440						9
Other			391						419						(28)						(7)
Total retail			8,358						8,002						356						4
Wholesale			4,226						4,373						(147)						(3)
Total sales			12,584						12,375						209						2		%
Average number of retail customers (in thousands)			843						835						8						1		%
Average revenue per MWh:
Retail			$	70.57					$	68.14					$	2.43					4		%
Wholesale			$	30.83					$	21.73					$	9.10					42		%
Heating degree days			2,760						3,081						(321)						(10)		%
Cooling degree days			7						6						1						17		%
Sources of energy (GWhs)(1):
Wind, solar and hydroelectric(2)			7,590						8,337						(747)						(9)		%
Coal			2,654						2,277						377						17
Nuclear			971						823						148						18
Natural gas			394						225						169						75
Total energy generated			11,609						11,662						(53)						—
Energy purchased			1,209						883						326						37
Total			12,818						12,545						273						2		%
Average cost of energy per MWh:
Energy generated(3)			$	7.78					$	5.74					$	2.04					36		%
Energy purchased			$	85.92					$	63.85					$	22.07					35		%

(1)    GWh amounts are net of energy used by the related generating facilities.

(2)    All or some of the renewable energy attributes associated with generation from these sources may be: (a) used in future years to comply with RPS or other regulatory requirements or (b) sold to third parties in the form of renewable energy credits or other environmental commodities.

(3)    The average cost per MWh of energy generated includes only the cost of fuel associated with the generating facilities.

108

---

Natural Gas Utility Margin

A comparison of key operating results related to natural gas utility margin is as follows:

			First Quarter
			2026						2025						Change
Utility margin (in millions):
Operating revenue			$	390					$	345					$	45					13		%
Natural gas purchased for resale			290						245						45						18
Utility margin			$	100					$	100					$	—					—		%
Throughput (000's Dths):
Residential			23,656						25,565						(1,909)						(7)		%
Commercial			11,205						12,095						(890)						(7)
Industrial			1,587						1,777						(190)						(11)
Other			72						41						31						76
Total retail sales			36,520						39,478						(2,958)						(7)
Wholesale sales			11,858						10,396						1,462						14
Total sales			48,378						49,874						(1,496)						(3)
Natural gas transportation service			31,491						30,641						850						3
Total throughput			79,869						80,515						(646)						(1)		%
Average number of retail customers (in thousands)			821						805						16						2		%
Average revenue per retail Dth sold			$	8.66					$	7.44					$	1.22					16		%
Heating degree days			2,932						3,193						(261)						(8)		%
Average cost of natural gas per retail Dth sold			$	6.39					$	5.31					$	1.08					20		%
Combined retail and wholesale average cost of natural gas per Dth sold			$	6.00					$	4.93					$	1.07					22		%

Quarter Ended March 31, 2026, Compared to Quarter Ended March 31, 2025

MidAmerican Energy -

Electric utility margin increased $10 million, or 2%, for the first quarter of 2026 compared to 2025 primarily due to:

•$11 million increase in retail utility margin primarily due to $18 million from higher customer usage and $4 million from price impacts related to changes in sales mix, partially offset by $6 million from the unfavorable impact of weather and $6 million from lower recoveries through bill riders (partially offset in operations and maintenance expense and income tax benefit). Retail customer volumes increased 4.4%; partially offset by

•a $1 million decrease in wholesale utility margin, driven by a $3 million, or 3.4%, decrease in sales volumes due to lower wind generation, partially offset by a $3 million increase in margin per unit reflecting higher market prices.

Operations and maintenance decreased $7 million, or 3%, for the first quarter of 2026 compared to 2025 primarily due to lower electric distribution costs of $7 million, lower employee and other administrative costs of $6 million and lower nuclear generation costs of $5 million, partially offset by higher customer account expense of $5 million and higher electric transmission costs of $5 million.

109

---

Depreciation and amortization decreased $30 million, or 10%, for the first quarter of 2026 compared to 2025 primarily due to $51 million from lower Iowa revenue sharing accruals, partially offset by $15 million related to new and repowered wind-powered generating facilities and other plant placed in-service and $6 million from a regulatory mechanism that provides customers the retail energy benefits of certain wind-powered generation projects.

Property and other taxes increased $4 million, or 9%, for the first quarter of 2026 compared to 2025 primarily due to higher replacement and wind turbine property taxes.

Interest expense increased $4 million, or 4%, for the first quarter of 2026 compared to 2025 primarily due to the debt issuance in November 2025.

Allowance for borrowed and equity funds decreased $2 million, or 8%, for the first quarter of 2026 compared to 2025 primarily due to lower construction work-in-progress balances related to wind-powered generation projects.

Other, net decreased $2 million, or 40%, for the first quarter of 2026 compared to 2025 primarily due to lower cash surrender values of corporate-owned life insurance policies from unfavorable market performance.

Income tax benefit decreased $20 million, or 8%, for the first quarter of 2026 compared to 2025. The effective tax rate was (675)% and 5,900% for the three-month periods ended March 31, 2026 and 2025, respectively. The $20 million decrease was primarily due to lower PTCs from lower wind generation of $17 million and higher pre-tax income.

MidAmerican Funding -

Income tax benefit decreased $18 million, or 8%, for the first quarter of 2026 compared to 2025. The effective tax rate was (807)% and 2,950% for the three-month periods ended March 31, 2026 and 2025, respectively. The $18 million decrease was primarily due to the factors discussed for MidAmerican Energy.

Liquidity and Capital Resources

As of March 31, 2026, the total net liquidity for MidAmerican Energy and MidAmerican Funding was as follows (in millions):

MidAmerican Energy:
Cash and cash equivalents			$	529
Credit facilities, maturing 2026 and 2028			1,505
Less:
Tax-exempt bond support			(258)
Net credit facilities			1,247
MidAmerican Energy total net liquidity			$	1,776
MidAmerican Funding:
MidAmerican Energy total net liquidity			$	1,776
MHC, Inc. credit facility, maturing 2026			4
MidAmerican Funding total net liquidity			$	1,780

Operating Activities

MidAmerican Energy's net cash flows from operating activities for the three-month periods ended March 31, 2026 and 2025, were $182 million and $268 million, respectively. MidAmerican Funding's net cash flows from operating activities for the three-month periods ended March 31, 2026 and 2025, were $174 million and $259 million, respectively. Cash flows from operating activities reflect higher payments related to fuel and energy costs and higher payments to vendors, partially offset by higher collections from electric and natural gas customers.

The timing of MidAmerican Energy's income tax cash flows from period to period can be significantly affected by the estimated federal income tax payment methods selected and assumptions made for each payment date.

110

---

Investing Activities

MidAmerican Energy's net cash flows from investing activities for the three-month periods ended March 31, 2026 and 2025, were $(411) million and $(401) million, respectively. MidAmerican Funding's net cash flows from investing activities for the three-month periods ended March 31, 2026 and 2025, were $(411) million and $(401) million, respectively. Net cash flows from investing activities consist almost entirely of capital expenditures. Refer to "Future Uses of Cash" for further discussion of capital expenditures. Purchases and proceeds related to marketable securities substantially consist of activity within the Quad Cities Generating Station nuclear decommissioning trust and other trust investments.

Financing Activities

MidAmerican Energy's net cash flows from financing activities for the three-month periods ended March 31, 2026 and 2025 were $87 million and $(14) million, respectively. MidAmerican Funding's net cash flows from financing activities for the three-month periods ended March 31, 2026 and 2025, were $93 million and $(7) million, respectively. In 2026 and 2025, MidAmerican Energy repaid $1 million and $14 million of long-term debt, respectively. In 2026 and 2025, MidAmerican Funding received $6 million and $7 million, respectively, through its note payable with BHE.

Debt Authorizations and Related Matters

Short-term Debt

MidAmerican Energy has authority from the FERC to issue, through April 2, 2028, commercial paper and bank notes aggregating $1.5 billion. MidAmerican Energy has a $1.5 billion unsecured credit facility expiring in June 2028. The credit facility, which supports MidAmerican Energy's commercial paper program and its variable-rate tax-exempt bond obligations and provides for the issuance of letters of credit, has a variable interest rate based on the Secured Overnight Financing Rate, plus a spread that varies based on MidAmerican Energy's credit ratings for senior unsecured long-term debt securities. Additionally, MidAmerican Energy has a $5 million unsecured credit facility for general corporate purposes.

Long-term Debt and Preferred Stock

MidAmerican Energy currently has an effective shelf registration statement filed with the SEC to issue an unspecified amount of long-term debt securities and preferred stock through October 2028. MidAmerican Energy has authorization from the FERC to issue, through June 30, 2027, long-term debt securities up to an aggregate of $2.1 billion and preferred stock up to an aggregate of $500 million. MidAmerican Energy has authorization from the Illinois Commerce Commission through April 24, 2028, to issue long-term debt securities up to an aggregate of $2.75 billion and preferred stock up to an aggregate of $500 million.

Future Uses of Cash

MidAmerican Energy and MidAmerican Funding have available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, the issuance of commercial paper, the use of unsecured revolving credit facilities and other sources. These sources are expected to provide funds required for current operations, capital expenditures, debt retirements and other capital requirements. The availability and terms under which MidAmerican Energy and MidAmerican Funding have access to external financing depends on a variety of factors, including their credit ratings, investors' judgment of risk and conditions in the overall capital markets, including the condition of the utility industry.

Capital Expenditures

Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, impacts to customer rates; changes in environmental and other rules and regulations; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; load projections; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital.

111

---

MidAmerican Energy's historical and forecast capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items, are as follows (in millions):

			Three-Month Periods												Annual
			Ended March 31,												Forecast
			2025						2026						2026
Wind generation			$	77					$	64					$	998
Electric distribution			81						72						360
Electric transmission			51						44						355
Solar generation			—						12						162
Other			196						226						695
Total			$	405					$	418					$	2,570

MidAmerican Energy's capital expenditures provided above consist of the following:

•Wind generation includes the construction, acquisition, repowering and operation of wind-powered generating facilities in Iowa.

◦Construction of wind-powered generating facilities totaling $— million and $54 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for the construction of additional wind-powered generating facilities totals $238 million for the remainder of 2026.

◦Repowering of wind-powered generating facilities totaling $56 million and $14 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for the repowering of wind-powered generating facilities totals $644 million for the remainder of 2026. MidAmerican Energy expects its repowered facilities to meet Internal Revenue Service guidelines for the re-establishment of PTCs under the prevailing wage and apprenticeship guidelines for 10 years from the date the facilities are placed in-service.

•Electric distribution includes expenditures for new facilities to meet retail demand growth and for replacement of existing facilities to maintain system reliability.

•Electric transmission includes expenditures to meet retail demand growth, upgrades to accommodate third-party generator requirements and replacement of existing facilities to maintain system reliability.

•Solar generation includes the construction and operation of solar-powered generating facilities totaling $12 million and $— million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending totals $150 million for the remainder of 2026.

•Remaining expenditures primarily relate to the construction of new natural gas-powered generating facilities in Iowa and routine projects for other generation, natural gas distribution, technology, facilities and other operational needs to serve existing and expected demand.

Material Cash Requirements

As of March 31, 2026, there have been no material changes in MidAmerican Energy's and MidAmerican Funding's cash requirements from the information provided in Item 7 of their Annual Report on Form 10-K for the year ended December 31, 2025, other than those disclosed in Note 8 of the Notes to Financial Statements in Part I, Item 1 of this Form 10-Q.

Regulatory Matters

MidAmerican Energy is subject to comprehensive regulation. Refer to "Regulatory Matters" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for discussion regarding MidAmerican Energy's current regulatory matters.

112

---

Environmental Laws and Regulations

MidAmerican Energy is subject to federal, state and local laws and regulations regarding air quality, climate change, emissions performance standards, water quality, coal ash disposal and other environmental matters that have the potential to impact MidAmerican Energy's current and future operations. In addition to imposing continuing compliance obligations, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance including fines, injunctive relief and other sanctions. These laws and regulations are administered by various federal, state and local agencies. MidAmerican Energy believes it is in material compliance with all applicable laws and regulations, although many are subject to interpretation that may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and MidAmerican Energy is unable to predict the impact of the changing laws and regulations on its operations and financial results.

Refer to "Environmental Laws and Regulations" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for additional information regarding environmental laws and regulations.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, impairment of goodwill, pension and other postretirement benefits and income taxes. For additional discussion of MidAmerican Energy's and MidAmerican Funding's critical accounting estimates, see Item 7 of their Annual Report on Form 10-K for the year ended December 31, 2025. There have been no significant changes in MidAmerican Energy's and MidAmerican Funding's assumptions regarding critical accounting estimates since December 31, 2025.

113

---

Nevada Power Company and its subsidiaries

Consolidated Financial Section

114

---

PART I

Item 1.Financial Statements

Report of Independent Registered Public Accounting Firm						116
Consolidated Balance Sheets						117
Consolidated Statements of Operations						118
Consolidated Statements of Changes in Shareholder's Equity						119
Consolidated Statements of Cash Flows						120
Notes to Consolidated Financial Statements
General						121
New Accounting Pronouncements						121
Cash and Cash Equivalents and Restricted Cash and Cash Equivalents						122
Property, Plant and Equipment, Net						122
Recent Financing Transactions						123
Income Taxes						123
Employee Benefit Plans						123
Risk Management and Hedging Activities						124
Fair Value Measurements						126
Commitments and Contingencies						127
Revenue from Contracts with Customers						128

115

---

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

Nevada Power Company

Results of Review of Interim Financial Information

We have reviewed the accompanying consolidated balance sheet of Nevada Power Company and subsidiaries ("Nevada Power") as of March 31, 2026, the related consolidated statements of operations, changes in shareholder's equity, and cash flows for the three-month periods ended March 31, 2026 and 2025, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of Nevada Power as of December 31, 2025, and the related consolidated statements of operations, changes in shareholder's equity, and cash flows for the year then ended (not presented herein); and in our report dated February 27, 2026, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2025, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of Nevada Power's management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to Nevada Power in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/ Deloitte & Touche LLP

Las Vegas, Nevada

May 1, 2026

116

---

NEVADA POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions, except share data)

			As of
			March 31,						December 31,
			2026						2025
ASSETS
Current assets:
Cash and cash equivalents			$	93					$	22
Trade receivables, net			228						243
Amounts due from affiliate			70						40
Inventories			227						230
Regulatory assets			44						120
Prepayments			94						60
Other current assets			20						25
Total current assets			776						740
Property, plant and equipment, net			10,605						10,423
Regulatory assets			433						433
Other assets			356						379
Total assets			$	12,170					$	11,975
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities:
Accounts payable			$	339					$	536
Amounts due to affiliates			296						88
Accrued interest			56						48
Accrued employee expenses			29						79
Short-term debt			—						50
Current portion of long-term debt			—						93
Customer deposits			60						56
Other current liabilities			170						117
Total current liabilities			950						1,067
Senior debt			3,306						3,305
Junior subordinated debt			297						297
Finance lease obligations			243						248
Regulatory liabilities			974						980
Deferred income taxes			825						837
Other long-term liabilities			674						551
Total liabilities			7,269						7,285
Commitments and contingencies (Note 10)
Shareholder's equity:
Common stock - $1.00 stated value; 1,000 shares authorized, issued and outstanding			—						—
Additional paid-in capital			3,323						3,123
Retained earnings			1,579						1,568
Accumulated other comprehensive loss, net			(1)						(1)
Total shareholder's equity			4,901						4,690
Total liabilities and shareholder's equity			$	12,170					$	11,975
The accompanying notes are an integral part of the consolidated financial statements.

117

---

NEVADA POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

									Three-Month Periods
									Ended March 31,
															2026						2025
Operating revenue															$	491					$	431
Operating expenses:
Cost of fuel and energy															240						213
Operations and maintenance															90						78
Depreciation and amortization															103						98
Property and other taxes															15						14
Total operating expenses															448						403
Operating income															43						28
Other income (expense):
Interest expense															(55)						(55)
Capitalized interest															5						4
Allowance for equity funds															10						8
Interest and dividend income															4						3
Other, net															6						3
Total other income (expense)															(30)						(37)
Income (loss) before income tax expense (benefit)															13						(9)
Income tax expense (benefit)															2						(1)
Net income (loss)															$	11					$	(8)
The accompanying notes are an integral part of these consolidated financial statements.

118

---

NEVADA POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY (Unaudited)

(Amounts in millions, except shares)

																														Accumulated
																		Additional												Other						Total
						Common Stock												Paid-in						Retained						Comprehensive						Shareholder's
						Shares						Amount						Capital						Earnings						Loss, Net						Equity
Balance, December 31, 2024						1,000						$	—					$	2,943					$	1,506					$	(1)					$	4,448
Net loss						—						—						—						(8)						—						(8)
Dividends declared						—						—						—						(185)						—						(185)
Balance, March 31, 2025						1,000						$	—					$	2,943					$	1,313					$	(1)					$	4,255
Balance, December 31, 2025						1,000						$	—					$	3,123					$	1,568					$	(1)					$	4,690
Net income						—						—						—						11						—						11
Contributions						—						—						200						—						—						200
Balance, March 31, 2026						1,000						$	—					$	3,323					$	1,579					$	(1)					$	4,901
The accompanying notes are an integral part of these consolidated financial statements.

119

---

NEVADA POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Cash flows from operating activities:
Net income (loss)			$	11					$	(8)
Adjustments to reconcile net income (loss) to net cash flows from operating activities:
Depreciation and amortization			103						98
Allowance for equity funds			(10)						(8)
Deferred energy			56						(10)
Amortization of deferred energy			20						13
Other changes in regulatory assets and liabilities			3						(7)
Deferred income taxes and amortization of investment tax credits			1						5
Other, net			8						1
Changes in other operating assets and liabilities:
Trade receivables and other assets			12						117
Inventories			4						(14)
Accounts payable and other liabilities			107						(17)
Net cash flows from operating activities			315						170
Cash flows from investing activities:
Capital expenditures			(380)						(283)
Net cash flows from investing activities			(380)						(283)
Cash flows from financing activities:
Proceeds from long-term debt			—						297
Repayments of long-term debt			(93)						—
Net repayment of short-term debt			(50)						—
Contributions from parent			200						—
Dividends paid			—						(185)
Other, net			78						(6)
Net cash flows from financing activities			135						106
Net change in cash and cash equivalents and restricted cash and cash equivalents			70						(7)
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period			35						42
Cash and cash equivalents and restricted cash and cash equivalents at end of period			$	105					$	35
The accompanying notes are an integral part of these consolidated financial statements.

120

---

NEVADA POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    General

Nevada Power Company and its subsidiaries ("Nevada Power"), is a wholly owned subsidiary of NV Energy, Inc. ("NV Energy"), a holding company that also owns Sierra Pacific Power Company and its subsidiaries ("Sierra Pacific") and certain other subsidiaries. Nevada Power is a U.S. regulated electric utility company serving retail customers, including residential, commercial and industrial customers, primarily in the Las Vegas, North Las Vegas, Henderson and adjoining areas. NV Energy is an indirect wholly owned subsidiary of Berkshire Hathaway Energy Company ("BHE"). BHE is a holding company based in Des Moines, Iowa that has investments in subsidiaries principally engaged in energy businesses. BHE is a wholly owned subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The accompanying Consolidated Financial Statements and Notes to Consolidated Financial Statements should be read in conjunction with Nevada Power's Annual Report on Form 10-K for the year ended December 31, 2025. The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2026, and for the three-month periods ended March 31, 2026 and 2025. The Consolidated Statements of Comprehensive Income have been omitted as net income equals comprehensive income for the three-month periods ended March 31, 2026 and 2025. The results of operations for the three-month period ended March 31, 2026, are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in Nevada Power's Annual Report on Form 10-K for the year ended December 31, 2025, describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in Nevada Power's accounting policies or its assumptions regarding significant accounting estimates during the three-month period ended March 31, 2026.

Segment Information

Nevada Power currently has one reportable segment, its regulated electric utility operations, which derives its revenue from regulated retail sales of electricity to residential, commercial, and industrial customers and from wholesale sales. Nevada Power's chief operating decision maker ("CODM") is its President and Chief Executive Officer. Net income, as reported on the Consolidated Statements of Operations, is considered by the CODM in allocating resources and capital. When making decisions about the allocation of resources and capital, the CODM generally considers actual results versus historical results, budgets or forecasts, and state regulatory ratemaking results as well as unique risks and opportunities. The significant segment expense information regularly provided to the CODM aligns with the captions presented on the Consolidated Statements of Operations. Nevada Power's segment capital expenditures are reported on the Consolidated Statements of Cash Flows as capital expenditures. Nevada Power's segment assets are reported on the Consolidated Balance Sheets as total assets.

(2)    New Accounting Pronouncements

In November 2024, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures Subtopic 220-40, "Disaggregation of Income Statement Expenses" which addresses requests from investors for more detailed information about certain expenses and requires disclosure of the amounts of purchases of inventory, employee compensation, depreciation and intangible asset amortization included in each relevant expense caption presented on the income statement. This guidance, as clarified in ASU 2025-01, is effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. Early adoption is permitted and should be applied on a prospective basis, however retrospective application is permitted. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

121

---

In December 2025, the FASB issued ASU No. 2025-10, Government Grants Topic 832, "Accounting for Government Grants Received by Business Entities" which establishes accounting for government grants received by an entity, including guidance for a grant related to an asset and a grant related to income. This guidance also requires, consistent with current disclosure requirements, that an entity provide disclosures including the nature of the government grant received, the accounting policies used to account for the grant, and significant terms and conditions of the grant. This guidance is effective for interim and annual reporting periods beginning after December 15, 2028. Early adoption is permitted and can be applied using either a modified prospective approach, a modified retrospective approach or a retrospective approach. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

(3)    Cash and Cash Equivalents and Restricted Cash and Cash Equivalents

Cash equivalents consist of funds invested in money market mutual funds, U.S. Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted cash and cash equivalents consist of funds restricted by the Public Utilities Commission of Nevada ("PUCN") for a certain renewable energy contract. A reconciliation of cash and cash equivalents and restricted cash and cash equivalents as presented on the Consolidated Statements of Cash Flows is outlined below and disaggregated by the line items in which they appear on the Consolidated Balance Sheets (in millions):

			As of
			March 31,						December 31,
			2026						2025
Cash and cash equivalents			$	93					$	22
Restricted cash and cash equivalents included in other current assets			12						13
Total cash and cash equivalents and restricted cash and cash equivalents			$	105					$	35

(4)    Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

									As of
			Depreciable Life						March 31,						December 31,
									2026						2025
Utility plant:
Generation			30 - 65 years						$	5,587					$	5,542
Transmission			55 - 75 years						1,886						1,886
Distribution			24 - 70 years						5,115						5,031
Intangible plant and other			5 - 65 years						998						951
Utility plant									13,586						13,410
Accumulated depreciation and amortization									(4,461)						(4,383)
Utility plant, net									9,125						9,027
Nonregulated, net of accumulated depreciation and amortization			40 years						1						1
									9,126						9,028
Construction work-in-progress									1,479						1,395
Property, plant and equipment, net									$	10,605					$	10,423

122

---

(5)    Recent Financing Transactions

Tax Exempt Bonds

In March 2026, Nevada Power repurchased the following series of fixed-rate tax-exempt bonds: $40 million of its Clark County, Nevada Revenue Bonds Series 2017, due 2036, $40 million of its Coconino County, Arizona Pollution Control Corporation Revenue Bonds, Series 2017A, due 2032, and $13 million of its Coconino County, Arizona Pollution Control Corporate Revenue Bonds, Series 2017B, due 2039. Nevada Power purchased these bonds as required by the bond indentures. Nevada Power is holding these bonds and can re-offer them at a future date.

(6)    Income Taxes

Berkshire Hathaway includes BHE and its subsidiaries in its U.S. federal income tax return. Consistent with established regulatory practice, Nevada Power's provision for federal income tax has been computed on a stand-alone basis, and substantially all of its currently payable or receivable income tax is remitted to or received from BHE pursuant to a tax allocation agreement. For current federal and state income taxes, Nevada Power had a net receivable from BHE of $2 million and $3 million as of March 31, 2026 and December 31, 2025, respectively. Nevada Power received no net cash payments for federal income tax from BHE for each of the three-month periods ended March 31, 2026 and 2025.

A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income (loss) before income tax expense (benefit) is as follows (amounts in millions):

												Three-Month Periods
												Ended March 31,
												2026												2025
												Amount						Percent						Amount						Percent
U.S. Federal statutory income tax rate												$	3					21.0		%				$	(2)					21.0		%
Energy-related tax credits												(1)						(5.6)						—						—
Effects of ratemaking(1)												—						—						1						(9.9)
Effective income tax rate												$	2					15.4		%				$	(1)					11.1		%

(1)Effects of ratemaking is primarily attributable to activity associated with excess deferred income taxes.

Energy-related tax credits relate to production tax credits ("PTCs") and investment tax credits ("ITCs") from Nevada Power's solar-powered generating facilities and energy storage properties. Federal renewable electricity PTCs are earned as energy from qualifying solar-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Solar-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in-service. Federal renewable electricity ITCs are tax credits that reduce the income tax liability by a percentage of the cost from certain qualifying solar-powered generating facilities or energy storage properties over their useful lives. The percentage of the credit varies depending on attributes of the project up to a maximum of 50 percent.

(7)    Employee Benefit Plans

Nevada Power is a participant in benefit plans sponsored by NV Energy. The NV Energy Retirement Plan includes a qualified pension plan ("Qualified Pension Plan") and a supplemental executive retirement plan and a restoration plan (collectively, "Non‑Qualified Pension Plans") that provide pension benefits for eligible employees. The NV Energy Comprehensive Welfare Benefit and Cafeteria Plan provides certain postretirement health care and life insurance benefits for eligible retirees ("Other Postretirement Plans") on behalf of Nevada Power. Amounts attributable to Nevada Power were allocated from NV Energy based upon the current, or in the case of retirees, previous, employment location. Offsetting regulatory assets and liabilities have been recorded related to the amounts not yet recognized as a component of net periodic benefit costs that will be included in regulated rates. Net periodic benefit costs not included in regulated rates are included in accumulated other comprehensive loss, net.

123

---

Amounts receivable from (payable to) NV Energy are included on the Consolidated Balance Sheets and consist of the following (in millions):

			As of
			March 31,						December 31,
			2026						2025
Qualified Pension Plan:
Other assets			$	46					$	46
Non-Qualified Pension Plans:
Other current liabilities			(1)						(1)
Other long-term liabilities			(5)						(5)
Other Postretirement Plans:
Other assets			17						16

(8)    Risk Management and Hedging Activities

Nevada Power is exposed to the impact of market fluctuations in commodity prices and interest rates. Nevada Power is principally exposed to electricity and natural gas market fluctuations primarily through Nevada Power's obligation to serve retail customer load in its regulated service territory. Nevada Power's load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity and wholesale electricity that is purchased and sold. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather, market liquidity, generating facility availability, customer usage, storage, and transmission and transportation constraints. The actual cost of fuel and purchased power is recoverable through the deferred energy mechanism. Interest rate risk exists on variable-rate debt and future debt issuances. Nevada Power does not engage in proprietary trading activities.

Nevada Power has established a risk management process that is designed to identify, assess, manage and report on each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, Nevada Power uses commodity derivative contracts, which may include forwards, futures, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. Nevada Power manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed-rate long-term debt and by monitoring market changes in interest rates. Additionally, Nevada Power may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, to mitigate Nevada Power's exposure to interest rate risk. Nevada Power does not hedge all of its commodity price and interest rate risks, thereby exposing the unhedged portion to changes in market prices. There have been no significant changes in Nevada Power's accounting policies related to derivatives. Refer to Note 9 for additional information related to the fair value measurements associated with derivative contracts.

124

---

The following table, which excludes contracts that have been designated as normal under the normal purchases and normal sales exception afforded by GAAP, summarizes the fair value of Nevada Power's derivative contracts, on a gross basis, and reconciles those amounts presented on a net basis on the Consolidated Balance Sheets (in millions):

															Derivative
															Contracts -						Other
															Current						Long-term
															Liabilities						Liabilities						Total
As of March 31, 2026
Not designated as hedging contracts(1):
Commodity liabilities															$	(30)					$	(21)					$	(51)
As of December 31, 2025
Not designated as hedging contracts(1):
Commodity liabilities															$	(27)					$	(14)					$	(41)

(1)Nevada Power's commodity derivatives not designated as hedging contracts are included in regulated rates. As of March 31, 2026, a regulatory asset of $51 million was recorded related to the net derivative liability of $51 million. As of December 31, 2025, a regulatory asset of $41 million was recorded related to the net derivative liability of $41 million.

Derivative Contract Volumes

The following table summarizes the net notional amounts of outstanding commodity derivative contracts with fixed price terms that comprise the mark-to-market values as of (in millions):

			Unit of						March 31,						December 31,
			Measure						2026						2025
Electricity purchases			Megawatt hours						2						2
Natural gas purchases			Decatherms						171						131

Credit Risk

Nevada Power is exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent Nevada Power's counterparties have similar economic, industry or other characteristics and due to direct and indirect relationships among the counterparties. Before entering into a transaction, Nevada Power analyzes the financial condition of each significant wholesale counterparty, establishes limits on the amount of unsecured credit to be extended to each counterparty and evaluates the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, Nevada Power enters into netting and collateral arrangements that may include margining and cross-product netting agreements and obtain third-party guarantees, letters of credit and cash deposits. If required, Nevada Power exercises rights under these arrangements, including calling on the counterparty's credit support arrangement.

Collateral and Contingent Features

In accordance with industry practice, certain wholesale agreements, including derivative contracts, contain credit support provisions that in part base certain collateral requirements on credit ratings for senior unsecured debt as reported by one or more of the recognized credit rating agencies. These agreements may either specifically provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels ("credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance" if there is a material adverse change in Nevada Power's creditworthiness. These rights can vary by contract and by counterparty. As of March 31, 2026, Nevada Power's credit ratings for its senior secured debt and its issuer credit ratings for subordinated debt from the recognized credit rating agencies were investment grade.

125

---

The aggregate fair value of Nevada Power's derivative contracts in liability positions with specific credit-risk-related contingent features totaled $5 million as of March 31, 2026, and December 31, 2025, which represents the amount of collateral to be posted if all credit risk related contingent features for derivative contracts in liability positions had been triggered. Nevada Power's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation or other factors.

(9)    Fair Value Measurements

The carrying value of Nevada Power's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. Nevada Power has various financial assets and liabilities that are measured at fair value on the Consolidated Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

•Level 1 — Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that Nevada Power has the ability to access at the measurement date.

•Level 2 — Inputs include 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 that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).

•Level 3 — Unobservable inputs reflect Nevada Power's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. Nevada Power develops these inputs based on the best information available, including its own data.

The following table presents Nevada Power's financial assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions):

			Input Levels for Fair Value Measurements
			Level 1						Level 2						Level 3						Total
As of March 31, 2026:
Assets:
Money market mutual funds			$	77					$	—					$	—					$	77
Investment funds			6						—						—						6
			$	83					$	—					$	—					$	83
Liabilities:
Commodity derivatives			$	—					$	—					$	(51)					$	(51)
As of December 31, 2025:
Assets:
Money market mutual funds			$	19					$	—					$	—					$	19
Investment funds			5						—						—						5
			$	24					$	—					$	—					$	24
Liabilities:
Commodity derivatives			$	—					$	—					$	(41)					$	(41)

126

---

Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which Nevada Power transacts. When quoted prices for identical contracts are not available, Nevada Power uses forward price curves. Forward price curves represent Nevada Power's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. Nevada Power bases its forward price curves upon internally developed models, with internal and external fundamental data inputs. Market price quotations for certain electricity and natural gas trading hubs are not as readily obtainable due to markets that are not active. Given that limited market data exists for these contracts, Nevada Power uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The model incorporates a mid-market pricing convention (the mid‑point price between bid and ask prices) as a practical expedient for valuing its assets and liabilities measured and reported at fair value. The determination of the fair value for derivative contracts not only includes counterparty risk, but also the impact of Nevada Power's nonperformance risk on its liabilities, which as of March 31, 2026, and December 31, 2025, had an immaterial impact to the fair value of its derivative contracts. As such, Nevada Power considers its derivative contracts to be valued using Level 3 inputs.

Nevada Power's investments in money market mutual funds and investment funds are stated at fair value. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value.

The following table reconciles the beginning and ending balances of Nevada Power's commodity derivative assets and liabilities measured at fair value on a recurring basis using significant Level 3 inputs (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Beginning balance															$	(41)					$	(57)
Changes in fair value recognized in regulatory assets															(14)						(24)
Settlements															4						8
Ending balance															$	(51)					$	(73)

Nevada Power's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of Nevada Power's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The following table presents the carrying value and estimated fair value of Nevada Power's debts (in millions):

			As of March 31, 2026												As of December 31, 2025
			Carrying						Fair						Carrying						Fair
			Value						Value						Value						Value
Long-term debt			$	3,603					$	3,551					$	3,695					$	3,688

(10)    Commitments and Contingencies

Environmental Laws and Regulations

Nevada Power is subject to federal, state and local laws and regulations regarding climate change, renewable portfolio standards, air and water quality, emissions performance standards, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact Nevada Power's current and future operations. Nevada Power believes it is in material compliance with all applicable laws and regulations.

127

---

Accrual for Customer Refund

Nevada Power's accrual in connection with customer refunds arising from an ongoing regulatory proceeding, reflecting its commitment to transparency and regulatory compliance, was $46 million as of March 31, 2026 and December 31, 2025. Nevada Power filed an Offer of Compromise with the PUCN in January 2026 to settle the regulatory proceeding, inclusive of the amount accrued in 2025, that was accepted by the PUCN in February 2026. Refunds are anticipated to be made to customers in mid-2026.

Legal Matters

Nevada Power is party to a variety of legal actions arising out of the normal course of business. Nevada Power does not believe that such normal and routine litigation will have a material impact on its consolidated financial results.

(11)    Revenue from Contracts with Customers

The following table summarizes Nevada Power's revenue from contracts with customers ("Customer Revenue") by line of business, with further disaggregation of retail by customer class (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Customer Revenue:
Retail:
Residential															$	234					$	217
Commercial															118						98
Industrial															118						97
Other															4						—
Total fully bundled															474						412
Distribution only service															4						4
Total retail															478						416
Wholesale, transmission and other															12						14
Total Customer Revenue															490						430
Other revenue															1						1
Total operating revenue															$	491					$	431

128

---

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

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of Nevada Power during the periods included herein. Explanations include management's best estimate of the impact of weather, customer growth, usage trends and other factors. This discussion should be read in conjunction with Nevada Power's historical unaudited Consolidated Financial Statements and Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q. Nevada Power's actual results in the future could differ significantly from the historical results.

Results of Operations for the First Quarter of 2026 and 2025

Overview

Net income for the first quarter of 2026 was $11 million, an increase of $19 million compared to 2025 primarily due to higher electric utility margin and higher capitalized interest and allowance for equity funds. These items were partially offset by higher operations and maintenance expense, increased depreciation and amortization expense and increased income tax expense. Utility margin increased primarily due to higher retail rates and higher energy efficiency implementation revenue. Retail customer volumes, including distribution only service customers, increased 4.6% primarily due to the favorable impact of weather, customer usage patterns and an increase in the average number of customers. Energy generated volumes decreased 7% for the first quarter of 2026 compared to 2025 primarily due to lower natural gas-fueled generation. Wholesale electricity sales volumes decreased 48% and energy purchased volumes decreased 14%.

Non-GAAP Financial Measure

Management utilizes various key financial measures that are prepared in accordance with GAAP, as well as non-GAAP financial measures such as utility margin, to help evaluate results of operations. Utility margin is calculated as electric operating revenue less cost of fuel and energy, which are captions presented on the Consolidated Statements of Operations.

Nevada Power's cost of fuel and energy is generally recovered from its retail customers through regulatory recovery mechanisms and as a result, changes in Nevada Power's expenses included in regulatory recovery mechanisms result in comparable changes to revenue. As such, management believes utility margin more appropriately and concisely explains results of operations rather than a discussion of revenue and cost of fuel and energy separately. Management believes the presentation of utility margin provides meaningful and valuable insight into the information management considers important to understanding the business and a measure of comparability to others in the industry.

Utility margin is not a measure calculated in accordance with GAAP and should be viewed as a supplement to, and not a substitute for, operating income which is the most directly comparable financial measure prepared in accordance with GAAP. The following table provides a reconciliation of utility margin to operating income (in millions):

						First Quarter
						2026						2025						Change
Utility margin:
Operating revenue						$	491					$	431					$	60		14		%
Cost of fuel and energy						240						213						27			13
Utility margin						251						218						33			15
Operations and maintenance						90						78						12			15
Depreciation and amortization						103						98						5			5
Property and other taxes						15						14						1			7
Operating income						$	43					$	28					$	15		54		%

129

---

Utility Margin

A comparison of key operating results related to utility margin is as follows:

						First Quarter
						2026						2025						Change
Utility margin (in millions):
Operating revenue						$	491					$	431					$	60		14		%
Cost of fuel and energy						240						213						27			13
Utility margin						$	251					$	218					$	33		15		%
Sales (GWhs):
Residential						1,644						1,533						111			7		%
Commercial						1,041						997						44			4
Industrial						1,428						1,397						31			2
Other						44						39						5			13
Total fully bundled(1)						4,157						3,966						191			5
Distribution only service						673						650						23			4
Total retail						4,830						4,616						214			5
Wholesale						50						96						(46)			(48)
Total GWhs sold						4,880						4,712						168			4		%
Average number of retail customers (in thousands)						1,056						1,046						10			1		%
Average revenue per MWh:
Retail - fully bundled(1)						$	114.28					$	103.95					$	10.33		10		%
Wholesale						$	34.03					$	44.90					$	(10.87)		(24)		%
Heating degree days						596						917						(321)			(35)		%
Cooling degree days						293						60						233			*
Sources of energy (GWhs)(2)(3):
Natural gas						3,097						3,323						(226)			(7)		%
Renewables						77						91						(14)			(15)
Total energy generated						3,174						3,414						(240)			(7)
Energy purchased						1,109						1,291						(182)			(14)
Total						4,283						4,705						(422)			(9)		%
Average cost of energy per MWh(2)(4):
Energy generated						$	43.75					$	34.25					$	9.50		28		%
Energy purchased						$	91.13					$	74.53					$	16.60		22		%

*    Not meaningful

(1)    Fully bundled includes sales to customers for combined energy, transmission and distribution services.

(2)    The average cost of energy per MWh and sources of energy excludes 234 GWhs and 112 GWhs of gas generated energy that is purchased at cost by related parties for the first quarter of 2026 and 2025, respectively.

(3)    GWh amounts are net of energy used by the related generating facilities.

(4)    The average cost of energy per MWh includes only the cost of fuel associated with the generating facilities, purchased power and deferrals.

130

---

Quarter Ended March 31, 2026, Compared to Quarter Ended March 31, 2025

Utility margin increased $33 million, or 15%, for the first quarter of 2026 compared to 2025 primarily due to:

•$27 million of higher electric retail utility margin primarily due to higher retail rates from the 2025 regulatory rate review with new rates effective October 2025. Retail customer volumes, including distribution only service customers, increased 4.6% primarily due to favorable changes in weather, customer usage patterns and an increase in the average number of customers;

•$4 million of higher energy efficiency implementation revenue and

•$3 million of higher other retail revenue from lower regulatory amortizations.

Operations and maintenance increased $12 million, or 15%, for the first quarter of 2026 compared to 2025 primarily due to higher administrative and general costs and higher regulatory amortizations from the 2025 regulatory rate review, partially offset by lower plant operations and maintenance costs.

Depreciation and amortization increased $5 million, or 5%, for the first quarter of 2026 compared to 2025 primarily due to higher plant placed in-service and higher amortizations from intangible plant software.

Capitalized interest and allowance for equity funds increased $3 million, or 25%, for the first quarter of 2026 compared to 2025 primarily due to higher construction work-in-progress.

Interest and dividend income increased $1 million, or 33%, for the first quarter of 2026 compared to 2025 primarily due to lower interest income, mainly from lower carrying charges on regulatory balances.

Income tax expense increased $3 million for the first quarter of 2026 compared to 2025. The effective tax rate was 15% and 11% for the three-month periods ended March 31, 2026 and 2025, respectively. The $3 million increase was primarily due to higher pretax income and lower benefit from the effects of ratemaking, partially offset by higher PTCs and ITCs.

Liquidity and Capital Resources

As of March 31, 2026, Nevada Power's total net liquidity was as follows (in millions):

Cash and cash equivalents			$	93
Credit facility, maturing 2028			600
Less:
Short-term debt			—
Net credit facility			600
Total net liquidity			$	693

Operating Activities

Net cash flows from operating activities for the three-month periods ended March 31, 2026 and 2025, were $315 million and $170 million, respectively. The change was primarily due to the timing of payments for operating costs and lower payments related to fuel and energy costs, partially offset by lower collections from customers and higher income tax payments.

The timing of Nevada Power's income tax cash flows from period to period can be significantly affected by the estimated federal income tax payment methods and assumptions made for each payment date.

Investing Activities

Net cash flows from investing activities for the three-month periods ended March 31, 2026 and 2025, were $(380) million and $(283) million, respectively. The change was primarily due to increased capital expenditures. Refer to "Future Uses of Cash" for further discussion of capital expenditures.

131

---

Financing Activities

Net cash flows from financing activities for the three-month periods ended March 31, 2026 and 2025, were $135 million and $106 million, respectively. The change was primarily due to higher contributions from NV Energy, Inc., lower dividends paid to NV Energy, Inc. and higher customer receipts from contributions in aid of construction, partially offset by lower net proceeds from the issuance of junior subordinated debt and higher payments of debt.

In April 2026, Nevada Power received contributions from NV Energy, Inc. of $200 million.

For a discussion of recent financing transactions, refer to Note 5 of Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q.

Debt Authorizations

Nevada Power currently has financing authority from the PUCN consisting of the ability to: (1) establish debt issuances limited to a debt ceiling of $5.5 billion (excluding borrowings under Nevada Power's $600 million secured credit facility); and (2) maintain a revolving credit facility of up to $1.3 billion. As of March 31, 2026, approximately $1.8 billion of debt capacity remains available under this authorization. Nevada Power currently has an effective shelf registration statement filed with the SEC to issue an additional $1.8 billion of general and refunding mortgage securities and unsecured debt securities through December 2027.

Future Uses of Cash

Nevada Power has available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, the use of its secured revolving credit facility, capital contributions and other sources. These sources are expected to provide funds required for current operations, capital expenditures, debt retirements and other capital requirements. The availability and terms under which Nevada Power has access to external financing depends on a variety of factors, including Nevada Power's credit ratings, investors' judgment of risk and conditions in the overall capital markets, including the condition of the utility industry.

Capital Expenditures

Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, changes in environmental and other rules and regulations; impacts to customers' rates; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; load projections; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital. Prudently incurred expenditures for compliance-related items such as pollution control technologies, replacement generation and associated operating costs are generally incorporated into Nevada Power's regulated retail rates. Expenditures for certain assets may ultimately include acquisition of existing assets.

Historical and forecast capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items are as follows (in millions):

			Three-Month Periods												Annual
			Ended March 31,												Forecast
			2025						2026						2026
Electric transmission			$	83					$	152					$	682
Electric distribution			82						74						414
Solar generation and electric battery storage			4						15						34
Wildfire prevention			2						7						33
Other			112						132						331
Total			$	283					$	380					$	1,494

132

---

Nevada Power receives PUCN approval through its IRP filings for various projects and has included estimates from IRP filings as well as potential future filings in its forecast capital expenditures for 2026. These estimates are likely to change as a result of the RFP process, continued evaluation and future IRP filing refinements. Nevada Power's capital expenditures include the following:

•Electric transmission includes both growth projects and operating expenditures. Growth projects primarily relate to the Nevada Utilities' Greenlink Nevada transmission expansion program totaling $144 million and $72 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for the Greenlink Nevada transmission expansion program expected to be placed in-service in 2027 and 2028 totals $485 million for the remainder of 2026. Operating expenditures consist of routine expenditures for transmission and other infrastructure needed to serve existing and expected demand.

•Electric distribution includes both growth projects and operating expenditures consisting of routine expenditures for distribution needed to serve existing and expected demand. Growth expenditures include spending on new customer connections totaling $34 million and $35 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for new customer connections totals $115 million for the remainder of 2026.

•Solar generation and electric battery storage primarily consist of a 400-MW solar photovoltaic facility with an additional 400 MWs of co-located battery storage that is being developed in Churchill County, Nevada with ownership share approved by the PUCN of 10% for Nevada Power and 90% for Sierra Pacific. Commercial operation of the solar facility is expected by early 2027 and the co-located battery storage reached commercial operation in March 2026.

•Wildfire prevention includes both growth and operating expenditures related to projects included in a comprehensive natural disaster protection plan filed and approved by the PUCN. These projects include, but are not limited to, rebuilding distribution lines with covered conductor, converting overhead distribution lines to underground and copper wire and pole replacement projects.

•Other includes both growth projects and operating expenditures. Operating expenditures consist of turbine upgrades at several generating facilities, information technology expenditures, routine expenditures for generation, other operating projects and other infrastructure needed to serve existing and expected demand.

2024 Joint Integrated Resource Plan

In October 2025, the Nevada Utilities submitted a Joint Application for approval of the First Amendment to the 2024 Joint Integrated Resource Plan. The First Amendment seeks approval to enter into a 20-year power purchase agreement with the developer for an additional 150-MW battery energy storage system that will reduce the Nevada Utilities' open position beginning in the summer of 2027. The battery energy storage system will be co-located with the existing Dodge Flat solar and battery facility in Washoe County, Nevada. In January 2026, the Nevada Utilities filed a stipulation with the PUCN that reflected a settlement among participating parties and largely accepted the First Amendment as filed, including approval of the 150-MW battery energy storage system power purchase agreement. A final order approving the stipulation was received in February 2026.

Material Cash Requirements

As of March 31, 2026, there have been no material changes outside the normal course of business in material cash requirements from the information provided in Item 7 of Nevada Power's Annual Report on Form 10-K for the year ended December 31, 2025, other than those disclosed in Note 6 of the Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q.

Regulatory Matters

Nevada Power is subject to comprehensive regulation. Refer to "Regulatory Matters" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for discussion regarding Nevada Power's current regulatory matters.

133

---

Environmental Laws and Regulations

Nevada Power is subject to federal, state and local laws and regulations regarding air quality, climate change, emissions performance standards, water quality, coal ash disposal and other environmental matters that have the potential to impact Nevada Power's current and future operations. In addition to imposing continuing compliance obligations, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance including fines, injunctive relief and other sanctions. These laws and regulations are administered by various federal, state and local agencies. Nevada Power believes it is in material compliance with all applicable laws and regulations, although many are subject to interpretation that may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and Nevada Power is unable to predict the impact of the changing laws and regulations on its operations and financial results.

Refer to "Environmental Laws and Regulations" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for additional information regarding environmental laws and regulations.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Consolidated Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, impairment of long-lived assets and income taxes. For additional discussion of Nevada Power's critical accounting estimates, see Item 7 of Nevada Power's Annual Report on Form 10‑K for the year ended December 31, 2025. There have been no significant changes in Nevada Power's assumptions regarding critical accounting estimates since December 31, 2025.

134

---

Sierra Pacific Power Company and its subsidiaries

Consolidated Financial Section

135

---

PART I

Item 1.Financial Statements

Report of Independent Registered Public Accounting Firm						137
Consolidated Balance Sheets						138
Consolidated Statements of Operations						139
Consolidated Statements of Changes in Shareholder's Equity						140
Consolidated Statements of Cash Flows						141
Notes to Consolidated Financial Statements
General						142
New Accounting Pronouncements						142
Cash and Cash Equivalents and Restricted Cash and Cash Equivalents						143
Property, Plant and Equipment, Net						143
Recent Financing Transactions						143
Income Taxes						144
Employee Benefit Plans						144
Risk Management and Hedging Activities						145
Fair Value Measurements						146
Commitments and Contingencies						148
Revenue from Contracts with Customers						149
Segment Information						149

136

---

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

Sierra Pacific Power Company

Results of Review of Interim Financial Information

We have reviewed the accompanying consolidated balance sheet of Sierra Pacific Power Company and subsidiaries ("Sierra Pacific") as of March 31, 2026, the related consolidated statements of operations, changes in shareholder's equity, and cash flows for the three-month periods ended March 31, 2026 and 2025, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of Sierra Pacific as of December 31, 2025, and the related consolidated statements of operations, changes in shareholder's equity, and cash flows for the year then ended (not presented herein); and in our report dated February 27, 2026, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2025, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of Sierra Pacific's management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to Sierra Pacific in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/ Deloitte & Touche LLP

Las Vegas, Nevada

May 1, 2026

137

---

SIERRA PACIFIC POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions, except share data)

			As of
			March 31,						December 31,
			2026						2025
ASSETS
Current assets:
Cash and cash equivalents			$	501					$	5
Trade receivables, net			92						108
Income taxes receivable			153						—
Amounts due from affiliates			281						196
Inventories			152						151
Regulatory assets			54						56
Prepayments			84						20
Other current assets			6						19
Total current assets			1,323						555
Property, plant and equipment, net			6,339						6,056
Regulatory assets			228						218
Other assets			233						216
Total assets			$	8,123					$	7,045
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities:
Accounts payable			$	531					$	519
Amounts due to affiliate			109						208
Accrued employee expenses			24						85
Current portion of long-term debt			410						410
Regulatory liabilities			86						72
Other current liabilities			150						85
Total current liabilities			1,310						1,379
Long-term debt			1,117						1,116
Junior subordinated debt			1,039						446
Regulatory liabilities			440						391
Deferred income taxes			356						390
Other long-term liabilities			552						342
Total liabilities			4,814						4,064
Commitments and contingencies (Note 10)
Shareholder's equity:
Common stock - $3.75 stated value, 1,000 shares authorized, issued and outstanding			—						—
Additional paid-in capital			2,861						2,561
Retained earnings			449						421
Accumulated other comprehensive loss, net			(1)						(1)
Total shareholder's equity			3,309						2,981
Total liabilities and shareholder's equity			$	8,123					$	7,045
The accompanying notes are an integral part of the consolidated financial statements.

138

---

SIERRA PACIFIC POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Operating revenue:
Regulated electric			$	235					$	236
Regulated natural gas			37						49
Total operating revenue			272						285
Operating expenses:
Cost of fuel and energy			113						115
Cost of natural gas purchased for resale			18						28
Operations and maintenance			71						60
Depreciation and amortization			45						40
Property and other taxes			7						6
Total operating expenses			254						249
Operating income			18						36
Other income (expense):
Interest expense			(31)						(24)
Allowance for borrowed funds			8						3
Allowance for equity funds			25						10
Interest and dividend income			4						3
Other, net			4						2
Total other income (expense)			10						(6)
Income before income tax expense (benefit)			28						30
Income tax expense (benefit)			1						3
Net income			$	27					$	27
The accompanying notes are an integral part of these consolidated financial statements.

139

---

SIERRA PACIFIC POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY (Unaudited)

(Amounts in millions, except shares)

																														Accumulated
																		Additional												Other						Total
						Common Stock												Paid-in						Retained						Comprehensive						Shareholder's
						Shares						Amount						Capital						Earnings						Loss, Net						Equity
Balance, December 31, 2024						1,000						$	—					$	1,726					$	375					$	(1)					$	2,100
Net income						—						—						—						27						—						27
Contributions						—						—						275						—						—						275
Balance, March 31, 2025						1,000						$	—					$	2,001					$	402					$	(1)					$	2,402
Balance, December 31, 2025						1,000						$	—					$	2,561					$	421					$	(1)					$	2,981
Net income						—						—						—						27						—						27
Contributions						—						—						300						—						—						300
Other equity transactions						—						—						—						1						—						1
Balance, March 31, 2026						1,000						$	—					$	2,861					$	449					$	(1)					$	3,309
The accompanying notes are an integral part of these consolidated financial statements.

140

---

SIERRA PACIFIC POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Cash flows from operating activities:
Net income			$	27					$	27
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization			45						40
Allowance for equity funds			(25)						(10)
Deferred energy			23						34
Amortization of deferred energy			(7)						—
Other changes in regulatory assets and liabilities			(1)						5
Deferred income taxes and amortization of investment tax credits			154						(13)
Other, net			—						(1)
Changes in other operating assets and liabilities:
Trade receivables and other assets			(122)						37
Inventories			(1)						(12)
Accounts payable and other liabilities			(272)						(80)
Net cash flows from operating activities			(179)						27
Cash flows from investing activities:
Capital expenditures			(251)						(173)
Net cash flows from investing activities			(251)						(173)
Cash flows from financing activities:
Proceeds from long-term debt			595						—
Contributions from parent			300						275
Other, net			31						(2)
Net cash flows from financing activities			926						273
Net change in cash and cash equivalents and restricted cash and cash equivalents			496						127
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period			10						24
Cash and cash equivalents and restricted cash and cash equivalents at end of period			$	506					$	151
The accompanying notes are an integral part of these consolidated financial statements.

141

---

SIERRA PACIFIC POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    General

Sierra Pacific Power Company and its subsidiaries ("Sierra Pacific"), is a wholly owned subsidiary of NV Energy, Inc. ("NV Energy"), a holding company that also owns Nevada Power Company and its subsidiaries ("Nevada Power") and certain other subsidiaries. Sierra Pacific is a U.S. regulated electric utility company serving retail customers, including residential, commercial and industrial customers and regulated retail natural gas customers primarily in northern Nevada. NV Energy is an indirect wholly owned subsidiary of Berkshire Hathaway Energy Company ("BHE"). BHE is a holding company based in Des Moines, Iowa that has investments in subsidiaries principally engaged in energy businesses. BHE is a wholly owned subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The accompanying Consolidated Financial Statements and Notes to Consolidated Financial Statements should be read in conjunction with Sierra Pacific's Annual Report on Form 10-K for the year ended December 31, 2025. The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2026, and for the three-month periods ended March 31, 2026 and 2025. The Consolidated Statements of Comprehensive Income have been omitted as net income equals comprehensive income for the three-month periods ended March 31, 2026 and 2025. The results of operations for the three-month period ended March 31, 2026, are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in Sierra Pacific's Annual Report on Form 10-K for the year ended December 31, 2025, describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in Sierra Pacific's accounting policies or its assumptions regarding significant accounting estimates during the three-month period ended March 31, 2026.

(2)    New Accounting Pronouncements

In November 2024, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures Subtopic 220-40, "Disaggregation of Income Statement Expenses" which addresses requests from investors for more detailed information about certain expenses and requires disclosure of the amounts of purchases of inventory, employee compensation, depreciation and intangible asset amortization included in each relevant expense caption presented on the income statement. This guidance, as clarified in ASU 2025-01, is effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. Early adoption is permitted and should be applied on a prospective basis, however retrospective application is permitted. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

In December 2025, the FASB issued ASU No. 2025-10, Government Grants Topic 832, "Accounting for Government Grants Received by Business Entities" which establishes accounting for government grants received by an entity, including guidance for a grant related to an asset and a grant related to income. This guidance also requires, consistent with current disclosure requirements, that an entity provide disclosures including the nature of the government grant received, the accounting policies used to account for the grant, and significant terms and conditions of the grant. This guidance is effective for interim and annual reporting periods beginning after December 15, 2028. Early adoption is permitted and can be applied using either a modified prospective approach, a modified retrospective approach or a retrospective approach. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

142

---

(3)    Cash and Cash Equivalents and Restricted Cash and Cash Equivalents

Cash equivalents consist of funds invested in money market mutual funds, U.S. Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted cash and cash equivalents consist of funds restricted by the Public Utilities Commission of Nevada ("PUCN") for a certain renewable energy contract. A reconciliation of cash and cash equivalents and restricted cash and cash equivalents as presented on the Consolidated Statements of Cash Flows is outlined below and disaggregated by the line items in which they appear on the Consolidated Balance Sheets (in millions):

			As of
			March 31,						December 31,
			2026						2025
Cash and cash equivalents			$	501					$	5
Restricted cash and cash equivalents included in other current assets			5						5
Total cash and cash equivalents and restricted cash and cash equivalents			$	506					$	10

(4)    Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

									As of
			Depreciable Life						March 31,						December 31,
									2026						2025
Utility plant:
Generation			25 - 70 years						$	1,730					$	1,413
Transmission			50 - 76 years						1,361						1,321
Electric distribution			20 - 76 years						2,341						2,298
Electric intangible plant and other			5 - 65 years						196						189
Natural gas distribution			35 - 70 years						609						591
Natural gas intangible plant and other			5 - 65 years						19						19
Common other			5 - 65 years						471						461
Utility plant									6,727						6,292
Accumulated depreciation and amortization									(2,252)						(2,296)
									4,475						3,996
Construction work-in-progress									1,864						2,060
Property, plant and equipment, net									$	6,339					$	6,056

(5)    Recent Financing Transactions

Junior Subordinated Debt

In March 2026, Sierra Pacific issued $600 million of its 6.375% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due September 2056. Sierra Pacific will pay interest on the junior subordinated notes at a rate of 6.375% through September 2031, subject to a reset every five years not to reset below 6.375%.

143

---

(6)    Income Taxes

Berkshire Hathaway includes BHE and its subsidiaries in its U.S. federal income tax return and BHE includes its subsidiaries in certain state income tax returns. Consistent with established regulatory practice, Sierra Pacific's provision for federal income tax has been computed on a stand-alone basis, and substantially all of its currently payable or receivable income tax is remitted to or received from BHE pursuant to a tax allocation agreement. For current federal and state income taxes, Sierra Pacific had a net receivable from BHE of $153 million and $— million as of March 31, 2026 and December 31, 2025, respectively. Sierra Pacific made no net cash payments for federal income tax to BHE for each of the three-month periods ended March 31, 2026 and 2025.

A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income before income tax expense (benefit) is as follows (amounts in millions):

			Three-Month Periods
			Ended March 31,
			2026												2025
			Amount						Percent						Amount						Percent
U.S. federal statutory income tax rate			$	6					21.0		%				$	6					21.0		%
Effects of ratemaking(1)			(5)						(17.4)						(3)						(11.0)
Effective income tax rate			$	1					3.6		%				$	3					10.0		%

(1)Effects of ratemaking is primarily attributable to activity associated with excess deferred income taxes.

(7)    Employee Benefit Plans

Sierra Pacific is a participant in benefit plans sponsored by NV Energy. The NV Energy Retirement Plan includes a qualified pension plan ("Qualified Pension Plan") and a supplemental executive retirement plan and a restoration plan (collectively, "Non‑Qualified Pension Plans") that provide pension benefits for eligible employees. The NV Energy Comprehensive Welfare Benefit and Cafeteria Plan provides certain postretirement health care and life insurance benefits for eligible retirees ("Other Postretirement Plans") on behalf of Sierra Pacific. Amounts attributable to Sierra Pacific were allocated from NV Energy based upon the current, or in the case of retirees, previous, employment location. Offsetting regulatory assets and liabilities have been recorded related to the amounts not yet recognized as a component of net periodic benefit costs that will be included in regulated rates. Net periodic benefit costs not included in regulated rates are included in accumulated other comprehensive loss, net.

Amounts receivable from (payable to) NV Energy are included on the Consolidated Balance Sheets and consist of the following (in millions):

			As of
			March 31,						December 31,
			2026						2025
Qualified Pension Plan:
Other assets			$	74					$	72
Non-Qualified Pension Plans:
Other current liabilities			(1)						(1)
Other long-term liabilities			(5)						(5)
Other Postretirement Plans:
Other assets			2						2

144

---

(8)    Risk Management and Hedging Activities

Sierra Pacific is exposed to the impact of market fluctuations in commodity prices and interest rates. Sierra Pacific is principally exposed to electricity, natural gas and coal market fluctuations primarily through Sierra Pacific's obligation to serve retail customer load in its regulated service territory. Sierra Pacific's load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity and wholesale electricity that is purchased and sold. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather, market liquidity, generating facility availability, customer usage, storage, and transmission and transportation constraints. The actual cost of fuel and purchased power is recoverable through the deferred energy mechanism. Interest rate risk exists on variable-rate debt and future debt issuances. Sierra Pacific does not engage in proprietary trading activities.

Sierra Pacific has established a risk management process that is designed to identify, assess, manage and report on each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, Sierra Pacific uses commodity derivative contracts, which may include forwards, futures, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. Sierra Pacific manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed-rate long-term debt and by monitoring market changes in interest rates. Additionally, Sierra Pacific may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, to mitigate Sierra Pacific's exposure to interest rate risk. Sierra Pacific does not hedge all of its commodity price and interest rate risks, thereby exposing the unhedged portion to changes in market prices. There have been no significant changes in Sierra Pacific's accounting policies related to derivatives. Refer to Note 9 for additional information on derivative contracts.

The following table, which excludes contracts that have been designated as normal under the normal purchases and normal sales exception afforded by GAAP, summarizes the fair value of Sierra Pacific's derivative contracts, on a gross basis, and reconciles those amounts presented on a net basis on the Consolidated Balance Sheets (in millions):

									Other												Other
									Long-term						Current						Long-term
									Assets						Liabilities						Liabilities						Total
As of March 31, 2026
Not designated as hedging contracts(1):
Commodity liabilities									$	—					$	(9)					$	(6)					$	(15)
As of December 31, 2025
Not designated as hedging contracts(1):
Commodity assets									$	1					$	—					$	—					$	1
Commodity liabilities									—						(8)						(4)						(12)
Total derivative - net basis									$	1					$	(8)					$	(4)					$	(11)

(1)Sierra Pacific's commodity derivatives not designated as hedging contracts are included in regulated rates. As of March 31, 2026, a net regulatory asset of $15 million was recorded related to the net derivative liability of $15 million. As of December 31, 2025, a net regulatory asset of $11 million was recorded related to the net derivative liability of $11 million.

The following table summarizes the net notional amounts of outstanding commodity derivative contracts with fixed price terms that comprise the mark-to-market values as of (in millions):

			Unit of						March 31,						December 31,
			Measure						2026						2025
Electricity purchases			Megawatt hours						1						1
Natural gas purchases			Decatherms						86						75

145

---

Credit Risk

Sierra Pacific is exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent Sierra Pacific's counterparties have similar economic, industry or other characteristics and due to direct and indirect relationships among the counterparties. Before entering into a transaction, Sierra Pacific analyzes the financial condition of each significant wholesale counterparty, establishes limits on the amount of unsecured credit to be extended to each counterparty and evaluates the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, Sierra Pacific enters into netting and collateral arrangements that may include margining and cross-product netting agreements and obtain third-party guarantees, letters of credit and cash deposits. If required, Sierra Pacific exercises rights under these arrangements, including calling on the counterparty's credit support arrangement.

Collateral and Contingent Features

In accordance with industry practice, certain wholesale agreements, including derivative contracts, contain credit support provisions that in part base certain collateral requirements on credit ratings for senior unsecured debt as reported by one or more of the recognized credit rating agencies. These agreements may either specifically provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels ("credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance" if there is a material adverse change in Sierra Pacific's creditworthiness. These rights can vary by contract and by counterparty. As of March 31, 2026, Sierra Pacific's credit ratings for its senior secured debt and its issuer credit ratings for subordinated debt from the recognized credit rating agencies were investment grade.

The aggregate fair value of Sierra Pacific's derivative contracts in liability positions with specific credit-risk-related contingent features totaled $— million as of March 31, 2026, and $1 million December 31, 2025, which represents the amount of collateral to be posted if all credit risk related contingent features for derivative contracts in liability positions had been triggered. Sierra Pacific's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation or other factors.

(9)    Fair Value Measurements

The carrying value of Sierra Pacific's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. Sierra Pacific has various financial assets and liabilities that are measured at fair value on the Consolidated Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

•Level 1 — Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that Sierra Pacific has the ability to access at the measurement date.

•Level 2 — Inputs include 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 that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).

•Level 3 — Unobservable inputs reflect Sierra Pacific's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. Sierra Pacific develops these inputs based on the best information available, including its own data.

146

---

The following table presents Sierra Pacific's financial assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions):

			Input Levels for Fair Value Measurements
			Level 1						Level 2						Level 3						Total
As of March 31, 2026:
Assets:
Money market mutual funds			$	532					$	—					$	—					$	532
Investment funds			1						—						—						1
			$	533					$	—					$	—					$	533
Liabilities:
Commodity derivatives			$	—					$	—					$	(15)					$	(15)
As of December 31, 2025:
Assets:
Commodity derivatives			$	—					$	—					$	1					$	1
Money market mutual funds			14						—						—						14
Investment funds			1						—						—						1
			$	15					$	—					$	1					$	16
Liabilities:
Commodity derivatives			$	—					$	—					$	(12)					$	(12)

Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which Sierra Pacific transacts. When quoted prices for identical contracts are not available, Sierra Pacific uses forward price curves. Forward price curves represent Sierra Pacific's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. Sierra Pacific bases its forward price curves upon internally developed models, with internal and external fundamental data inputs. Market price quotations for certain electricity and natural gas trading hubs are not as readily obtainable due to markets that are not active. Given that limited market data exists for these contracts, Sierra Pacific uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The model incorporates a mid-market pricing convention (the mid‑point price between bid and ask prices) as a practical expedient for valuing its assets and liabilities measured and reported at fair value. The determination of the fair value for derivative contracts not only includes counterparty risk, but also the impact of Sierra Pacific's nonperformance risk on its liabilities, which as of March 31, 2026, and December 31, 2025, had an immaterial impact to the fair value of its derivative contracts. As such, Sierra Pacific considers its derivative contracts to be valued using Level 3 inputs.

Sierra Pacific's investments in money market mutual funds and investment funds are stated at fair value. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value.

147

---

The following table reconciles the beginning and ending balances of Sierra Pacific's commodity derivative assets and liabilities measured at fair value on a recurring basis using significant Level 3 inputs (in millions):

									Three-Month Periods
									Ended March 31,
															2026						2025
Beginning balance															$	(11)					$	(13)
Changes in fair value recognized in regulatory assets															(4)						(7)
Settlements															—						1
Ending balance															$	(15)					$	(19)

Sierra Pacific's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of Sierra Pacific's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The following table presents the carrying value and estimated fair value of Sierra Pacific's long-term debt (in millions):

			As of March 31, 2026												As of December 31, 2025
			Carrying						Fair						Carrying						Fair
			Value						Value						Value						Value
Long-term debt			$	2,566					$	2,545					$	1,972					$	1,967

(10)    Commitments and Contingencies

Environmental Laws and Regulations

Sierra Pacific is subject to federal, state and local laws and regulations regarding climate change, renewable portfolio standards, air and water quality, emissions performance standards, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact Sierra Pacific's current and future operations. Sierra Pacific believes it is in material compliance with all applicable laws and regulations.

Accrual for Customer Refund

Sierra Pacific's accrual in connection with customer refunds arising from an ongoing regulatory proceeding, reflecting its commitment to transparency and regulatory compliance, was $14 million as of March 31, 2026 and December 31, 2025. Sierra Pacific filed an Offer of Compromise with the PUCN in January 2026 to settle the regulatory proceeding, inclusive of the amount accrued in 2025, that was accepted by the PUCN in February 2026. Refunds are anticipated to be made to customers in mid-2026.

Legal Matters

Sierra Pacific is party to a variety of legal actions arising out of the normal course of business. Sierra Pacific does not believe that such normal and routine litigation will have a material impact on its consolidated financial results.

148

---

(11)    Revenue from Contracts with Customers

The following table summarizes Sierra Pacific's revenue from contracts with customers ("Customer Revenue") by line of business, with further disaggregation of retail by customer class, including a reconciliation to Sierra Pacific's reportable segment information included in Note 12 (in millions):

			Three-Month Periods
			Ended March 31,
			2026																		2025
			Electric						Natural Gas						Total						Electric						Natural Gas						Total
Customer Revenue:
Retail:
Residential			$	89					$	23					$	112					$	93					$	32					$	125
Commercial			72						9						81						73						13						86
Industrial			52						2						54						48						4						52
Other			1						—						1						2						—						2
Total fully bundled			214						34						248						216						49						265
Distribution only service			2						—						2						2						—						2
Total retail			216						34						250						218						49						267
Wholesale, transmission and other			19						3						22						18						—						18
Total Customer Revenue			235						37						272						236						49						285
Other revenue			—						—						—						—						—						—
Total operating revenue			$	235					$	37					$	272					$	236					$	49					$	285

(12)    Segment Information

Sierra Pacific's chief operating decision maker ("CODM") is its President and Chief Executive Officer. Net income for each reportable segment is considered by the CODM in allocating resources and capital. When making decisions about the allocation of resources and capital to each reportable segment, the CODM generally considers actual results versus historical results, budgets or forecasts, and state regulatory ratemaking results as well as unique risks and opportunities.

Sierra Pacific has identified two reportable operating segments: regulated electric and regulated natural gas. The regulated electric segment derives most of its revenue from regulated retail sales of electricity to residential, commercial, and industrial customers and from wholesale sales. The regulated natural gas segment derives most of its revenue from regulated retail sales of natural gas to residential, commercial, and industrial customers and also obtains revenue by transporting natural gas owned by others through its distribution system. Pricing for regulated electric and regulated natural gas sales are established separately by the PUCN; therefore, management also reviews each segment separately to make decisions regarding allocation of resources and in evaluating performance.

149

---

The following tables provide information on a reportable segment basis (in millions):

			For the Three-Month Period Ended March 31, 2026
			Regulated Electric						Regulated Natural Gas						Total
Operating revenue			$	235					$	37					$	272
Cost of sales			113						18						131
Operations and maintenance			67						4						71
Depreciation and amortization			40						5						45
Interest expense			28						3						31
Interest and dividend income			4						—						4
Income tax expense (benefit)			—						1						1
Other segment items (1)			29						1						30
Net income			$	20					$	7					$	27
Capital expenditures			$	235					$	16					$	251

			For the Three-Month Period Ended March 31, 2025
			Regulated Electric						Regulated Natural Gas						Total
Operating revenue			$	236					$	49					$	285
Cost of sales			115						28						143
Operations and maintenance			54						6						60
Depreciation and amortization			35						5						40
Interest expense			22						2						24
Interest and dividend income			3						—						3
Income tax expense (benefit)			2						1						3
Other segment items (1)			9						—						9
Net income			$	20					$	7					$	27
Capital expenditures			$	159					$	14					$	173

									As of
															March 31,						December 31,
															2026						2025
Assets:
Regulated electric															$	7,030					$	6,541
Regulated natural gas															579						485
Regulated common assets(2)															514						19
Total assets															$	8,123					$	7,045

(1)    Consists principally of property and other taxes, allowance for borrowed and equity funds and other income (expenses).

(2)    Consists principally of cash and cash equivalents not included in either the regulated electric or regulated natural gas segments.

150

---

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

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of Sierra Pacific during the periods included herein. Explanations include management's best estimate of the impact of weather, customer growth, usage trends and other factors. This discussion should be read in conjunction with Sierra Pacific's historical unaudited Consolidated Financial Statements and Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q. Sierra Pacific's actual results in the future could differ significantly from the historical results.

Results of Operations for the First Quarter of 2026 and 2025

Overview

Net income for the first quarter of 2026 was $27 million, which is consistent with 2025 primarily due to higher allowance for borrowed and equity funds, lower tax expense and an increase in electric utility margin. These items are partially offset by higher operations and maintenance, higher interest expense, higher depreciation and amortization expense and a decrease in gas utility margin. Electric utility margin increased primarily due to higher transmission and wholesale revenue. Electric retail customer volumes, including distribution only service customers, increased by 3.6% primarily due to the favorable usage patterns and an increase in the average number of customers. Natural gas utility margin decreased primarily due to the unfavorable impact of weather. Energy generated volumes increased 7% for the first quarter of 2026 compared to 2025 primarily due to higher natural gas-fueled generation. Wholesale electricity sales volumes decreased 15% and energy purchased volumes increased 8%.

Non-GAAP Financial Measure

Management utilizes various key financial measures that are prepared in accordance with GAAP, as well as non-GAAP financial measures such as electric utility margin and natural gas utility margin, to help evaluate results of operations. Electric utility margin is calculated as electric operating revenue less cost of fuel and energy while natural gas utility margin is calculated as natural gas operating revenue less cost of natural gas purchased for resale, which are captions presented on the Consolidated Statements of Operations.

Sierra Pacific's cost of fuel and energy and cost of natural gas purchased for resale are generally recovered from its retail customers through regulatory recovery mechanisms and as a result, changes in Sierra Pacific's expenses included in recovery mechanisms result in comparable changes to revenue. As such, management believes electric utility margin and natural gas utility margin more appropriately and concisely explain results of operations rather than a discussion of revenue and cost of sales separately. Management believes the presentation of electric utility margin and natural gas utility margin provides meaningful and valuable insight into the information management considers important to understanding the business and a measure of comparability to others in the industry.

151

---

Electric utility margin and natural gas utility margin are not measures calculated in accordance with GAAP and should be viewed as a supplement to, and not a substitute for, operating income which is the most directly comparable financial measure prepared in accordance with GAAP. The following table provides a reconciliation of utility margin to operating income (in millions):

						First Quarter
						2026						2025						Change
Electric utility margin:
Operating revenue						$	235					$	236					$	(1)		—		%
Cost of fuel and energy						113						115						(2)			(2)
Electric utility margin						122						121						1			1		%
Natural gas utility margin:
Operating revenue						37						49						(12)			(24)		%
Natural gas purchased for resale						18						28						(10)			(36)
Natural gas utility margin						19						21						(2)			(10)		%
Utility margin						141						142						(1)			(1)		%
Operations and maintenance						71						60						11			18		%
Depreciation and amortization						45						40						5			13
Property and other taxes						7						6						1			17
Operating income						$	18					$	36					$	(18)		(50)		%

152

---

Electric Utility Margin

A comparison of key operating results related to electric utility margin is as follows:

						First Quarter
						2026						2025						Change
Utility margin (in millions):
Operating revenue						$	235					$	236					$	(1)		—		%
Cost of fuel and energy						113						115						(2)			(2)
Utility margin						$	122					$	121					$	1		1		%
Sales (GWhs):
Residential						647						670						(23)			(3)		%
Commercial						719						711						8			1
Industrial						787						691						96			14
Other						2						2						—			—
Total fully bundled(1)						2,155						2,074						81			4
Distribution only service						725						706						19			3
Total retail						2,880						2,780						100			4
Wholesale						168						198						(30)			(15)
Total GWhs sold						3,048						2,978						70			2		%
Average number of retail customers (in thousands)						389						384						5			1		%
Average revenue per MWh:
Retail - fully bundled(1)						$	99.18					$	103.88					$	(4.70)		(5)		%
Wholesale						$	77.28					$	60.02					$	17.26		29		%
Heating degree days						1,697						2,124						(427)			(20)		%
Cooling degree days						2						—						2			*
Sources of energy (GWhs)(2):
Natural gas						1,230						980						250			26		%
Coal						5						173						(168)			(97)
Renewables						1						1						—			—
Total energy generated						1,236						1,154						82			7
Energy purchased						751						696						55			8
Total						1,987						1,850						137			7		%
Average cost of energy per MWh(3):
Energy generated						$	41.25					$	46.39					$	(5.14)		(11)		%
Energy purchased						$	82.58					$	88.59					$	(6.01)		(7)		%

*    Not meaningful

(1)    Fully bundled includes sales to customers for combined energy, transmission and distribution services.

(2)    GWh amounts are net of energy used by the related generating facilities.

(3)    The average cost of energy per MWh includes only the cost of fuel associated with the generating facilities, purchased power and deferrals.

153

---

Natural Gas Utility Margin

A comparison of key operating results related to natural gas utility margin is as follows:

						First Quarter
						2026						2025						Change
Utility margin (in millions):
Operating revenue						$	37					$	49					$	(12)		(24)		%
Natural gas purchased for resale						18						28						(10)			(36)
Utility margin						$	19					$	21					$	(2)		(10)		%
Sold (000's Dths):
Residential						3,974						4,728						(754)			(16)		%
Commercial						2,070						2,427						(357)			(15)
Industrial						795						818						(23)			(3)
Total retail						6,839						7,973						(1,134)			(14)		%
Average number of retail customers (in thousands)						189						187						2			1		%
Average revenue per retail Dth sold						$	5.43					$	6.16					$	(0.73)		(12)		%
Heating degree days						1,697						2,124						(427)			(20)		%
Average cost of natural gas per retail Dth sold						$	2.63					$	3.56					$	(0.93)		(26)		%

Quarter Ended March 31, 2026, Compared to Quarter Ended March 31, 2025

Electric utility margin increased $1 million, or 1%, for the first quarter of 2026 compared to 2025 primarily due to:

•$3 million of higher transmission and wholesale revenue.

The increase in electric utility margin was partially offset by:

•$1 million of lower electric retail utility margin primarily due to unfavorable price impacts from changes in sales mix. This is primarily due to the unfavorable impact of weather, partially offset by retail customer volumes, including distribution only service customers, which increased 3.6% primarily due to an increase in the average number of customers and

•$1 million reduction of revenue for a regulatory liability recorded for the Tracy Area Master Plan (TAMP) project as directed by the 2024 Sierra Pacific regulatory rate review.

Natural gas utility margin decreased $2 million, or 10%, for the first quarter of 2026 compared to 2025 primarily due to the unfavorable impact of weather and customer usage patterns.

Operations and maintenance increased $11 million, or 18%, for the first quarter of 2026 compared to 2025 primarily due to higher general and administrative costs, higher insurance expense due to increased wildfire coverage and higher premiums associated with third-party liability coverage and higher regulatory amortizations.

Depreciation and amortization increased $5 million, or 13%, for the first quarter of 2026 compared to 2025 primarily due to higher plant placed in-service and higher amortizations from intangible plant software.

Interest expense increased $7 million, or 29%, for the first quarter of 2026 compared to 2025 primarily due to higher long-term debt.

Allowance for borrowed and equity funds increased $20 million, for the first quarter of 2026 compared to 2025 primarily due to higher construction work-in-progress.

154

---

Interest and dividend income increased $1 million, or 33%, for the first quarter of 2026 compared to 2025 primarily due to favorable interest income, mainly from higher carrying charges on regulatory balances.

Income tax expense decreased $2 million, or (67)%, for the first quarter of 2026 compared to 2025. The effective tax rate was 4% and 10% for the three-month periods ended March 31, 2026 and 2025, respectively. The $2 million decrease was primarily due to higher benefits from the effects of ratemaking.

Liquidity and Capital Resources

As of March 31, 2026, Sierra Pacific's total net liquidity was as follows (in millions):

Cash and cash equivalents			$	501
Credit facility, maturing 2028			400
Less:
Short-term debt			—
Net credit facility			400
Total net liquidity			$	901

Operating Activities

Net cash flows from operating activities for the three-month periods ended March 31, 2026 and 2025, were $(179) million and $27 million, respectively. The change was primarily due to the timing of payments for operating costs and higher payments related to fuel and energy costs, partially offset by increased collections from customers and lower interest payments.

The timing of Sierra Pacific's income tax cash flows from period to period can be significantly affected by the estimated federal income tax payment methods and assumptions made for each payment date.

Investing Activities

Net cash flows from investing activities for the three-month periods ended March 31, 2026 and 2025, were $(251) million and $(173) million, respectively. The change was primarily due to increased capital expenditures. Refer to "Future Uses of Cash" for further discussion of capital expenditures.

Financing Activities

Net cash flows from financing activities for the three-month periods ended March 31, 2026 and 2025, were $926 million and $273 million, respectively. The change was primarily due to higher proceeds from the issuance of junior subordinated debt, higher contributions from NV Energy, Inc. and higher customer receipts from contributions in aid of construction.

Debt Authorizations

Sierra Pacific currently has financing authority from the PUCN consisting of the ability to: (1) establish debt issuances limited to a debt ceiling of $4.0 billion (excluding borrowings under Sierra Pacific's $400 million secured credit facility); and (2) maintain a revolving credit facility of up to $600 million. As of March 31, 2026, approximately $1.3 billion of debt capacity remains available under this authorization. Sierra Pacific currently has an effective shelf registration statement filed with the SEC to issue an additional $1.5 billion of general and refunding mortgage securities and unsecured debt securities through April 2028.

155

---

Future Uses of Cash

Sierra Pacific has available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, the use of secured revolving credit facilities, capital contributions and other sources. These sources are expected to provide funds required for current operations, capital expenditures, debt retirements and other capital requirements. The availability and terms under which Sierra Pacific has access to external financing depends on a variety of factors, including Sierra Pacific's credit ratings, investors' judgment of risk associated with Sierra Pacific and conditions in the overall capital markets, including the condition of the utility industry.

Capital Expenditures

Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, changes in environmental and other rules and regulations; impacts to customers' rates; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; load projections; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital. Prudently incurred expenditures for compliance-related items such as pollution-control technologies, replacement generation and associated operating costs are generally incorporated into Sierra Pacific's regulated retail rates. Expenditures for certain assets may ultimately include acquisition of existing assets.

Historical and forecast capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items are as follows (in millions):

			Three-Month Periods												Annual
			Ended March 31,												Forecast
			2025						2026						2026
Electric transmission			$	48					$	40					$	531
Electric distribution			45						54						264
Solar generation and electric battery storage			62						45						161
Wildfire prevention			4						5						91
Other			14						107						659
Total			$	173					$	251					$	1,706

Sierra Pacific receives PUCN approval through its IRP filings for various projects and has included estimates from IRP filings as well as potential future filings in its forecast capital expenditures for 2026. These estimates are likely to change as a result of the RFP process, continued evaluation and future IRP filing refinements. Sierra Pacific's capital expenditures include the following:

•Electric transmission includes both growth projects and operating expenditures. Growth projects primarily relate to the Nevada Utilities' Greenlink Nevada transmission expansion program totaling $13 million and $34 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for the expansion program expected to be placed in-service in 2027 and 2028 totals $399 million for the remainder of 2026. Operating expenditures consist of routine expenditures for transmission and other infrastructure needed to serve existing and expected demand.

•Electric distribution includes both growth projects and operating expenditures consisting of routine expenditures for distribution needed to serve existing and expected demand. Growth expenditures include spending on new customer connections totaling $16 million and $10 million for the three-month periods ended March 31, 2026 and 2025, respectively. Planned spending for new customer connections totals $36 million for the remainder of 2026.

•Solar generation and electric battery storage primarily consist of a 400-MW solar photovoltaic facility with an additional 400 MWs of co-located battery storage that is being developed in Churchill County, Nevada with ownership share approved by the PUCN of 90% Sierra Pacific and 10% Nevada Power. Commercial operation of the solar facility is expected by early 2027 and the co-located battery storage reached commercial operation in March 2026.

156

---

•Wildfire prevention includes both growth and operating capital that include expenditures contained in a comprehensive natural disaster protection plan filed and approved by the PUCN. These projects include, but are not limited to, rebuilding distribution lines with covered conductor, converting overhead distribution lines to underground and copper wire and pole replacement projects.

•Other includes both growth projects and operating expenditures. Growth projects primarily consist of a repower project at the Valmy generating station to convert existing coal-fueled combustion to natural gas-fueled combustion, information technology expenditures, routine expenditures for generation, other operating projects and other infrastructure needed to serve existing and expected demand.

2024 Joint Integrated Resource Plan

In October 2025, the Nevada Utilities submitted a Joint Application for approval of the First Amendment to the 2024 Joint Integrated Resource Plan. The First Amendment seeks approval to enter into a 20-year power purchase agreement with the developer for an additional 150-MW battery energy storage system that will reduce the Nevada Utilities' open position beginning in the summer of 2027. The battery energy storage system will be co-located with the existing Dodge Flat solar and battery facility in Washoe County, Nevada. In January 2026, the Nevada Utilities filed a stipulation with the PUCN that reflected a settlement among participating parties and largely accepted the First Amendment as filed, including approval of the 150-MW battery energy storage system power purchase agreement. A final order approving the stipulation was received in February 2026.

2025 Natural Gas Triennial Integrated Resource Plan

In October 2025, Sierra Pacific filed its 2025 Natural Gas Triennial Integrated Resource Plan (the "2025 NGIRP") with the PUCN, covering the 2026 through 2028 action plan period. The filling seeks approval of forecasted natural gas demand, ten significant operational and capital projects, the 2025 DSM Plan, and related findings regarding the reasonableness of the forecast methodology, projected demand, cost-effectiveness of proposed investments, resource mix, greenhouse gas considerations, and impacts on low-income and historically underserved communities. The application also requests authorization to establish a regulatory asset account to record costs associated with a proposed Plexco Service Tee Cap Replacement Program addressing premature failures of certain service tee caps installed between 1990 and 1996, with recovery of amounts recorded in the regulatory asset account to be sought in a future general rate case. In January 2026, Sierra Pacific filed a stipulation with the PUCN that reflected a settlement among participating parties and largely accepted the NGIRP as filed with removal of the requested regulatory asset account to record costs associated with the Plexco Service Tee CAP Replacement Program. A final order approving the stipulation was received in February 2026.

Material Cash Requirements

As of March 31, 2026, there have been no material changes outside the normal course of business in material cash requirements from the information provided in Item 7 of Sierra Pacific's Annual Report on Form 10-K for the year ended December 31, 2025, other than those disclosed in Note 6 of the Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q.

Regulatory Matters

Sierra Pacific is subject to comprehensive regulation. Refer to "Regulatory Matters" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for discussion regarding Sierra Pacific's current regulatory matters.

157

---

Environmental Laws and Regulations

Sierra Pacific is subject to federal, state and local laws and regulations regarding air quality, climate change, emissions performance standards, water quality, coal ash disposal and other environmental matters that have the potential to impact Sierra Pacific's current and future operations. In addition to imposing continuing compliance obligations, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance including fines, injunctive relief and other sanctions. These laws and regulations are administered by various federal, state and local agencies. Sierra Pacific believes it is in material compliance with all applicable laws and regulations, although many are subject to interpretation that may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and Sierra Pacific is unable to predict the impact of the changing laws and regulations on its operations and financial results.

Refer to "Environmental Laws and Regulations" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for additional information regarding environmental laws and regulations.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Consolidated Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, impairment of long-lived assets and income taxes. For additional discussion of Sierra Pacific's critical accounting estimates, see Item 7 of Sierra Pacific's Annual Report on Form 10‑K for the year ended December 31, 2025. There have been no significant changes in Sierra Pacific's assumptions regarding critical accounting estimates since December 31, 2025.

158

---

Eastern Energy Gas Holdings, LLC and its subsidiaries

Consolidated Financial Section

159

---

PART I

Item 1.Financial Statements

Report of Independent Registered Public Accounting Firm						161
Consolidated Balance Sheets						162
Consolidated Statements of Operations						164
Consolidated Statements of Comprehensive Income						165
Consolidated Statements of Changes in Equity						166
Consolidated Statements of Cash Flows						167
Notes to Consolidated Financial Statements
General						168
New Accounting Pronouncements						169
Property, Plant and Equipment, Net						169
Investments and Restricted Cash and Cash Equivalents						170
Income Taxes						171
Employee Benefit Plans						171
Fair Value Measurements						172
Commitments and Contingencies						173
Revenue from Contracts with Customers						174
Components of Accumulated Other Comprehensive Loss, Net						175

160

---

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors of

Eastern Energy Gas Holdings, LLC

Results of Review of Interim Financial Information

We have reviewed the accompanying consolidated balance sheet of Eastern Energy Gas Holdings, LLC and subsidiaries ("Eastern Energy Gas") as of March 31, 2026, the related consolidated statements of operations, comprehensive income, changes in equity, and cash flows for the three-month periods ended March 31, 2026 and 2025, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of Eastern Energy Gas as of December 31, 2025, and the related consolidated statements of operations, comprehensive income, changes in equity, and cash flows for the year then ended (not presented herein); and in our report dated February 27, 2026, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2025, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of Eastern Energy Gas' management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to Eastern Energy Gas in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/ Deloitte & Touche LLP

Richmond, Virginia

May 1, 2026

161

---

EASTERN ENERGY GAS HOLDINGS, LLC AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions)

			As of
			March 31,						December 31,
			2026						2025
ASSETS
Current assets:
Cash and cash equivalents			$	86					$	80
Trade receivables, net			189						191
Receivables from affiliates			21						20
Notes receivable from affiliates			571						513
Inventories			158						155
Prepayments and other deferred charges			63						78
Natural gas imbalances			58						66
Other current assets			65						92
Total current assets			1,211						1,195
Property, plant and equipment, net			10,384						10,363
Goodwill			1,286						1,286
Investments			272						255
Other assets			108						98
Total assets			$	13,261					$	13,197

The accompanying notes are an integral part of these consolidated financial statements.

162

---

EASTERN ENERGY GAS HOLDINGS, LLC AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited) (continued)

(Amounts in millions)

			As of
			March 31,						December 31,
			2026						2025
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable			$	96					$	87
Accounts payable to affiliates			29						27
Accrued interest			76						58
Accrued property, income and other taxes			139						141
Regulatory liabilities			37						46
Current portion of long-term debt			287						293
Other current liabilities			79						81
Total current liabilities			743						733
Long-term debt			4,162						4,161
Regulatory liabilities			615						620
Deferred income taxes			674						621
Other long-term liabilities			129						115
Total liabilities			6,323						6,250
Commitments and contingencies (Note 8)
Equity:
Member's equity:
Membership interests			5,731						5,736
Accumulated other comprehensive loss, net			(29)						(31)
Total member's equity			5,702						5,705
Noncontrolling interests			1,236						1,242
Total equity			6,938						6,947
Total liabilities and equity			$	13,261					$	13,197

The accompanying notes are an integral part of these consolidated financial statements.

163

---

EASTERN ENERGY GAS HOLDINGS, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Operating revenue			$	652					$	578
Operating expenses:
Cost of gas			1						—
Operations and maintenance			126						130
Depreciation and amortization			89						87
Property and other taxes			35						35
Total operating expenses			251						252
Operating income			401						326
Other income (expense):
Interest expense, net			(55)						(52)
Allowance for equity funds			4						2
Interest and dividend income			8						2
Total other income (expense)			(43)						(48)
Income before income tax expense (benefit) and equity income (loss)			358						278
Income tax expense (benefit)			80						59
Equity income (loss)			27						26
Net income			305						245
Net income attributable to noncontrolling interests			58						45
Net income attributable to Eastern Energy Gas			$	247					$	200

The accompanying notes are an integral part of these consolidated financial statements.

164

---

EASTERN ENERGY GAS HOLDINGS, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Net income			$	305					$	245
Other comprehensive income, net of tax:
Unrecognized amounts on retirement benefits, net of tax of $1 and $—			1						—
Unrealized gains on cash flow hedges, net of tax of $1 and $—			1						—
Total other comprehensive income, net of tax			2						—
Comprehensive income			307						245
Comprehensive income attributable to noncontrolling interests			58						45
Comprehensive income attributable to Eastern Energy Gas			$	249					$	200

The accompanying notes are an integral part of these consolidated financial statements.

165

---

EASTERN ENERGY GAS HOLDINGS, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Unaudited)

(Amounts in millions)

																																	Accumulated
																																	Other
																											Membership						Comprehensive						Noncontrolling						Total
																											Interests						Loss, Net						Interests						Equity
Balance, December 31, 2024																											$	6,300					$	(35)					$	1,270					$	7,535
Net income																											200						—						45						245
Distributions																											(1,189)						—						(43)						(1,232)
Balance, March 31, 2025																											$	5,311					$	(35)					$	1,272					$	6,548
Balance, December 31, 2025																											$	5,736					$	(31)					$	1,242					$	6,947
Net income																											247						—						58						305
Other comprehensive income																											—						2						—						2
Distributions																											(252)						—						(64)						(316)
Balance, March 31, 2026																											$	5,731					$	(29)					$	1,236					$	6,938

The accompanying notes are an integral part of these consolidated financial statements.

166

---

EASTERN ENERGY GAS HOLDINGS, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Cash flows from operating activities:
Net income			$	305					$	245
Adjustments to reconcile net income to net cash flows from operating activities:
Gains on other items, net			(16)						—
Depreciation and amortization			89						87
Allowance for equity funds			(4)						(2)
Equity (income) loss, net of distributions			(18)						(11)
Changes in regulatory assets and liabilities			(11)						(15)
Deferred income taxes			51						42
Other, net			2						—
Changes in other operating assets and liabilities:
Trade receivables and other assets			32						22
Receivables from affiliates			(1)						(3)
Gas balancing activities			(4)						11
Accrued property, income and other taxes			1						(10)
Accounts payable to affiliates			2						1
Accounts payable and other liabilities			24						30
Net cash flows from operating activities			452						397
Cash flows from investing activities:
Capital expenditures			(92)						(55)
Proceeds from assignment of shale development rights			16						—
Proceeds from sales of marketable securities			3						7
Issuance of notes receivable to affiliates			(58)						(37)
Net cash flows from investing activities			(131)						(85)
Cash flows from financing activities:
Proceeds from long-term debt			—						1,187
Distributions to noncontrolling interests			(64)						(43)
Distributions to parent			(252)						(1,189)
Net cash flows from financing activities			(316)						(45)
Net change in cash and cash equivalents and restricted cash and cash equivalents			5						267
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period			113						61
Cash and cash equivalents and restricted cash and cash equivalents at end of period			$	118					$	328

The accompanying notes are an integral part of these consolidated financial statements.

167

---

EASTERN ENERGY GAS HOLDINGS, LLC AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    General

Eastern Energy Gas Holdings, LLC is a holding company, and together with its subsidiaries ("Eastern Energy Gas") conducts business activities consisting of Federal Energy Regulatory Commission ("FERC")-regulated interstate natural gas transmission systems and underground storage operations in the eastern region of the U.S. and operates Cove Point LNG, LP ("Cove Point"), a liquefied natural gas ("LNG") export, import and storage facility. Eastern Energy Gas holds 100% of the general partner interest and 75% of the limited partner interests of Cove Point. In addition, Eastern Energy Gas holds a 50% noncontrolling interest in Iroquois Gas Transmission System, L.P. ("Iroquois"), a 414-mile FERC-regulated interstate natural gas transmission system. Eastern Energy Gas is an indirect wholly owned subsidiary of Berkshire Hathaway Energy Company ("BHE"). BHE is a holding company headquartered in Des Moines, Iowa that has investments in subsidiaries principally engaged in energy businesses. BHE is a wholly owned subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The accompanying Consolidated Financial Statements and Notes to Consolidated Financial Statements should be read in conjunction with Eastern Energy Gas' Annual Report on Form 10-K for the year ended December 31, 2025. The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2026, and for the three-month periods ended March 31, 2026 and 2025. The results of operations for the three-month period ended March 31, 2026, are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in Eastern Energy Gas' Annual Report on Form 10-K for the year ended December 31, 2025, describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in Eastern Energy Gas' accounting policies or its assumptions regarding significant accounting estimates during the three-month period ended March 31, 2026.

Segment Information

Eastern Energy Gas currently has one reportable segment, which includes its natural gas transmission, storage and LNG operations. Eastern Energy Gas' chief operating decision maker ("CODM") is the President and Chief Executive Officer of the BHE Pipeline Group (which consists primarily of BHE GT&S, LLC, Northern Natural Gas Company and Kern River Gas Transmission Company). Net income attributable to Eastern Energy Gas, as reported on the Consolidated Statements of Operations, is considered by the CODM in allocating resources and capital. When making decisions about the allocation of resources and capital, the CODM generally considers actual results versus historical results, budgets or forecast, as well as unique risks and opportunities. The segment expense information regularly provided to the CODM aligns with the captions presented on the Consolidated Statements of Operations. The measure of segment assets is reported on the Consolidated Balance Sheets as total assets.

168

---

(2)    New Accounting Pronouncements

In November 2024, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures Subtopic 220-40, "Disaggregation of Income Statement Expenses" which addresses requests from investors for more detailed information about certain expenses and requires disclosure of the amounts of purchases of inventory, employee compensation, depreciation and intangible asset amortization included in each relevant expense caption presented on the income statement. This guidance, as clarified in ASU 2025-01, is effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. Early adoption is permitted and should be applied on a prospective basis, however retrospective application is permitted. Eastern Energy Gas is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

(3)    Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

									As of
									March 31,						December 31,
			Depreciable Life						2026						2025
Utility plant:
Interstate natural gas transmission assets			34 - 51 years						$	6,664					$	6,599
Storage assets			47 - 79 years						2,873						2,856
Intangible plant and other assets			4 - 53 years						528						514
Utility plant in-service									10,065						9,969
Accumulated depreciation and amortization									(3,606)						(3,555)
Utility plant in-service, net									6,459						6,414
Nonutility plant:
LNG facility			40 years						4,583						4,585
Accumulated depreciation and amortization									(933)						(901)
Nonutility plant, net									3,650						3,684
									10,109						10,098
Construction work-in-progress									275						265
Property, plant and equipment, net									$	10,384					$	10,363

Construction work-in-progress includes $261 million and $255 million as of March 31, 2026 and December 31, 2025, respectively, related to the construction of utility plant.

Assignment of Shale Development Rights

In September 2025, Eastern Gas Transmission and Storage, Inc. ("EGTS") signed an agreement to convey development rights over time to a natural gas producer for approximately 23,000 acres of Utica Shale and Point Pleasant formations underneath one of its natural gas storage fields. The agreement provides for payments to EGTS of approximately $49 million over a period of three years, and an overriding royalty interest in gas produced from the acreage. In January 2026, EGTS conveyed approximately 7,600 acres and received proceeds of $16 million from the initial conveyance. This transaction resulted in a $16 million ($12 million after-tax) gain recorded in operations and maintenance expense in its Consolidated Statements of Operations.

169

---

(4)    Investments and Restricted Cash and Cash Equivalents

Investments and restricted cash and cash equivalents consists of the following (in millions):

			As of
			March 31,						December 31,
			2026						2025
Investments:
Investment funds			$	5					$	8
Equity method investments:
Iroquois			267						247
Restricted cash and cash equivalents:
Customer deposits			32						33
Total investments and restricted cash and cash equivalents			$	304					$	288
Reflected as:
Other current assets			$	32					$	33
Noncurrent assets			272						255
Total investments and restricted cash and cash equivalents			$	304					$	288

Equity Method Investments

Eastern Energy Gas, through subsidiaries, holds 50% of Iroquois, which owns and operates an interstate natural gas transmission system located in the states of New York and Connecticut.

As of March 31, 2026, and December 31, 2025, the carrying amount of Eastern Energy Gas' investments exceeded its share of underlying equity in net assets by $130 million. The difference reflects equity method goodwill and is not being amortized. Eastern Energy Gas received distributions from its investments of $9 million and $15 million for the three-month periods ended March 31, 2026 and 2025, respectively.

Cash and Cash Equivalents and Restricted Cash and Cash Equivalents

Cash equivalents consist of funds invested in money market mutual funds, U.S. Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted cash and cash equivalents consist of customer deposits as allowed under the FERC gas tariffs. A reconciliation of cash and cash equivalents and restricted cash and cash equivalents as presented on the Consolidated Statements of Cash Flows is outlined below and disaggregated by the line items in which they appear on the Consolidated Balance Sheets (in millions):

			As of
			March 31,						December 31,
			2026						2025
Cash and cash equivalents			$	86					$	80
Restricted cash and cash equivalents included in other current assets			32						33
Total cash and cash equivalents and restricted cash and cash equivalents			$	118					$	113

170

---

(5)    Income Taxes

Berkshire Hathaway includes BHE and its subsidiaries in its U.S. federal income tax return and BHE includes its subsidiaries in certain state income tax returns. Consistent with established regulatory practice, Eastern Energy Gas' provision for federal and state income tax has been computed on a stand-alone basis, and substantially all of its currently payable or receivable income tax is remitted to or received from BHE pursuant to a tax allocation agreement. For current federal and state income taxes, Eastern Energy Gas had a payable to BHE of $63 million and $39 million as of March 31, 2026 and December 31, 2025, respectively.

A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income before income tax expense (benefit) is as follows (amounts in millions):

			Three-Month Periods
			Ended March 31,
			2026												2025
			Amount						Percent						Amount						Percent
U.S. federal statutory income tax rate			$	75					21.0		%				$	58					21.0		%
State and local income taxes, net of federal income tax			12						3.2						6						2.1
Nontaxable or nondeductible items:
Equity earnings			6						1.6						5						2.0
Non-controlling interest			(12)						(3.4)						(9)						(3.4)
Other, net			(1)						(0.1)						—						—
Other adjustments			—						—						(1)						(0.5)
Effective income tax rate			$	80					22.3		%				$	59					21.2		%

(6)    Employee Benefit Plans

Eastern Energy Gas is a participant in benefit plans sponsored by MidAmerican Energy Company ("MidAmerican Energy"), an affiliate. The MidAmerican Energy Company Retirement Plan includes a qualified pension plan that provides pension benefits for eligible employees. The MidAmerican Energy Company Welfare Benefit Plan provides certain postretirement health care and life insurance benefits for eligible retirees on behalf of Eastern Energy Gas. Eastern Energy Gas contributed $1 million to the MidAmerican Energy Company Retirement Plan for each of the three-month periods ended March 31, 2026 and 2025. Contributions related to these plans are reflected as net periodic benefit cost in operations and maintenance expense on the Consolidated Statements of Operations. Amounts attributable to Eastern Energy Gas were allocated from MidAmerican Energy in accordance with the intercompany administrative service agreement. Offsetting regulatory assets and liabilities have been recorded related to the amounts not yet recognized as a component of net periodic benefit costs that will be included in regulated rates. Net periodic benefit costs not included in regulated rates are included in accumulated other comprehensive loss, net. As of March 31, 2026, and December 31, 2025, Eastern Energy Gas' amount due to MidAmerican Energy associated with these plans and included in other long-term liabilities on the Consolidated Balance Sheets was $39 million.

171

---

(7)    Fair Value Measurements

The carrying value of Eastern Energy Gas' cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. Eastern Energy Gas has various financial assets and liabilities that are measured at fair value on the Consolidated Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

•Level 1 — Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that Eastern Energy Gas has the ability to access at the measurement date.

•Level 2 — Inputs include 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 that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).

•Level 3 — Unobservable inputs reflect Eastern Energy Gas' judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. Eastern Energy Gas develops these inputs based on the best information available, including its own data.

The following table presents Eastern Energy Gas' financial assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions):

						Input Levels for Fair Value Measurements
						Level 1						Level 2						Level 3						Total
As of March 31, 2026:
Assets:
Foreign currency exchange rate derivatives						$	—					$	5					$	—					$	5
Money market mutual funds						86						—						—						86
Equity securities:
Investment funds						5						—						—						5
						$	91					$	5					$	—					$	96
As of December 31, 2025:
Assets:
Foreign currency exchange rate derivatives						$	—					$	11					$	—					$	11
Money market mutual funds						80						—						—						80
Equity securities:
Investment funds						8						—						—						8
						$	88					$	11					$	—					$	99

Eastern Energy Gas' investments in money market mutual funds and investment funds are stated at fair value. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value.

172

---

Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchase or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which Eastern Energy Gas transacts. When quoted prices for identical contracts are not available, Eastern Energy Gas uses forward price curves. Forward price curves represent Eastern Energy Gas' estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. Eastern Energy Gas bases its forward price curves upon market price quotations, when available, or internally developed and commercial models, with internal and external fundamental data inputs. Market price quotations are obtained from independent brokers, exchanges, direct communication with market participants and actual transactions executed by Eastern Energy Gas. Market price quotations are generally readily obtainable for the applicable term of Eastern Energy Gas' outstanding derivative contracts; therefore, Eastern Energy Gas' forward price curves reflect observable market quotes. Market price quotations for certain natural gas trading hubs are not as readily obtainable due to the length of the contracts. Given that limited market data exists for these contracts, as well as for those contracts that are not actively traded, Eastern Energy Gas uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The estimated fair value of these derivative contracts is a function of underlying forward commodity prices, interest rates, currency rates, related volatility, counterparty creditworthiness and duration of contracts.

Eastern Energy Gas' long-term debt is carried at cost on the Consolidated Financial Statements. The fair value of Eastern Energy Gas' long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The following table presents the carrying value and estimated fair value of Eastern Energy Gas' long-term debt (in millions):

						As of March 31, 2026												As of December 31, 2025
						Carrying						Fair						Carrying						Fair
						Value						Value						Value						Value
Long-term debt						$	4,449					$	4,218					$	4,454					$	4,276

(8)    Commitments and Contingencies

Environmental Laws and Regulations

Eastern Energy Gas is subject to federal, state and local laws and regulations regarding air quality, climate change, emissions performance standards, water quality and other environmental matters that have the potential to impact its current and future operations. Eastern Energy Gas believes it is in material compliance with all applicable laws and regulations.

Legal Matters

Eastern Energy Gas is party to a variety of legal actions arising out of the normal course of business. Eastern Energy Gas does not believe that such normal and routine litigation will have a material impact on its consolidated financial results.

173

---

(9)    Revenue from Contracts with Customers

The following table summarizes Eastern Energy Gas' revenue from contracts with customers ("Customer Revenue") by regulated and nonregulated, with further disaggregation of regulated by line of business (in millions):

			Three-Month Periods
			Ended March 31,
			2026						2025
Customer Revenue:
Regulated:
Gas transmission and storage			$	339					$	332
Wholesale			2						1
Total regulated			341						333
Nonregulated			305						244
Total Customer Revenue			646						577
Other revenue(1)			6						1
Total operating revenue			$	652					$	578

(1)Other revenue consists primarily of revenue recognized in accordance with Accounting Standards Codification 815, "Derivative and Hedging" which includes unrealized gains and losses for derivatives not designated as hedges related to natural gas sales contracts, contingent fees from certain farmout agreements recognized in accordance with ASC 450, "Contingencies" and the royalties from the conveyance of mineral rights accounted for under Accounting Standards Codification 932, "Extractive Activities – Oil and Gas".

Eastern Energy Gas has recognized contract liabilities of $38 million and $43 million as of March 31, 2026, and December 31, 2025, respectively, due to the relationship between Eastern Energy Gas' performance and the customer's payment. Eastern Energy Gas recognizes revenue as it fulfills its obligations to provide services to its customers. During the three-month periods ended March 31, 2026 and 2025, Eastern Energy Gas recognized revenue of $11 million and $9 million, respectively, from the beginning contract liability balances.

Remaining Performance Obligations

The following table summarizes Eastern Energy Gas' revenue it expects to recognize in future periods related to significant unsatisfied remaining performance obligations for fixed contracts with expected durations in excess of one year as of March 31, 2026 (in millions):

			Performance obligations expected to be satisfied:
			Less than 12 months						More than 12 months						Total
Eastern Energy Gas			$	1,792					$	13,231					$	15,023

174

---

(10)    Components of Accumulated Other Comprehensive Loss, Net

The following table shows the change in accumulated other comprehensive loss by each component of other comprehensive income (loss), net of applicable income tax (in millions):

			Unrecognized																		Accumulated
			Amounts On						Unrealized												Other
			Retirement						Losses on Cash						Noncontrolling						Comprehensive
			Benefits						Flow Hedges						Interests						Loss, Net
Balance, December 31, 2024			$	(2)					$	(34)					$	1					$	(35)
Other comprehensive income			—						—						—						—
Balance, March 31, 2025			$	(2)					$	(34)					$	1					$	(35)
Balance, December 31, 2025			$	(1)					$	(31)					$	1					$	(31)
Other comprehensive income			1						1						—						2
Balance, March 31, 2026			$	—					$	(30)					$	1					$	(29)

175

---

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

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of Eastern Energy Gas during the periods included herein. This discussion should be read in conjunction with Eastern Energy Gas' historical Consolidated Financial Statements and Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q. Eastern Energy Gas' actual results in the future could differ significantly from the historical results.

Results of Operations for the First Quarter of 2026 and 2025

Overview

Net income attributable to Eastern Energy Gas for the first quarter of 2026 was $247 million, an increase of $47 million compared to 2025. Net income increased primarily due to higher earnings from Cove Point of $32 million, largely due to an increase in variable revenue, higher margin from regulated gas transmission and storage operations of $16 million and a gain from an agreement to convey development rights underneath one of its natural gas storage fields.

Quarter Ended March 31, 2026, Compared to Quarter Ended March 31, 2025

Operating revenue increased $74 million, or 13%, for the first quarter of 2026 compared to 2025, primarily due to an increase in Cove Point LNG variable revenue of $59 million due to higher volumes and higher prices from extremely cold weather in the first quarter of 2026 and an increase in royalties and other contingent fees from farmout agreements of $5 million.

Operations and maintenance decreased $4 million, or 3%, for the first quarter of 2026 compared to 2025, primarily due to a gain from an agreement to convey development rights underneath one of its natural gas storage fields of $16 million, partially offset by higher employee costs of $5 million, higher plant operations and maintenance costs of $3 million and an increase in charges from affiliates of $2 million.

Interest and dividend income increased $6 million for the first quarter of 2026 compared to 2025, primarily due to higher lending activity under BHE GT&S' intercompany revolving credit agreement.

Income tax expense increased $21 million, or 36%, for the first quarter of 2026 compared to 2025. The effective tax rate was 22% and 21% for the three-month periods ended March 31, 2026 and 2025, respectively. The $21 million increase was primarily due to higher pre-tax income and higher state income taxes.

Net income attributable to noncontrolling interests increased $13 million, or 29%, for the first quarter of 2026 compared to 2025, primarily due to higher net income attributable to Cove Point.

Liquidity and Capital Resources

As of March 31, 2026, Eastern Energy Gas' total net liquidity was as follows (in millions):

Cash and cash equivalents			$	86
Intercompany revolving credit agreement, maturing 2027			400
Total net liquidity			$	486

176

---

Operating Activities

Net cash flows from operating activities for the three-month periods ended March 31, 2026 and 2025 were $452 million and $397 million, respectively. The change is primarily due to favorable operating results, the timing of payments for operating costs and other working capital adjustments, partially offset by higher cash paid for interest and lower distributions from Iroquois.

Investing Activities

Net cash flows from investing activities for the three-month periods ended March 31, 2026 and 2025 were $(131) million and $(85) million, respectively. The change is primarily due to an increase in capital expenditures of $37 million, an increase in notes issued to its parent under an intercompany revolving credit agreement of $21 million and a decrease in proceeds from sales of marketable securities of $4 million, partially offset by proceeds from the assignment of shale development rights of $16 million.

Financing Activities

Net cash flows from financing activities for the three-month period ended March 31, 2026 were $(316) million and consisted of distributions to its indirect parent, BHE, of $252 million and distributions to noncontrolling interests from Cove Point of $64 million.

Net cash flows from financing activities for the three-month period ended March 31, 2025 were $(45) million. Sources of cash totaled $1.2 billion and consisted of proceeds from the issuance of long-term debt. Uses of cash totaled $1.2 billion and consisted of distributions to its indirect parent, BHE, of $1.2 billion and distributions to noncontrolling interests from Cove Point of $43 million.

Long-term debt

Eastern Energy Gas currently has an effective shelf registration statement filed with the SEC to issue an additional $400 million of long-term debt securities through January 2027.

Future Uses of Cash

Eastern Energy Gas has available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, intercompany revolving credit agreements, capital contributions and other sources. These sources are expected to provide funds required for current operations, capital expenditures, investments, debt retirements and other capital requirements. The availability and terms under which Eastern Energy Gas and each subsidiary has access to external financing depends on a variety of factors, including regulatory approvals, Eastern Energy Gas' credit ratings, investors' judgment of risk and conditions in the overall capital markets, including the condition of the natural gas transmission and storage and LNG export, import and storage industries.

Capital Expenditures

Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, new growth projects and the timing of growth projects; changes in environmental and other rules and regulations; impacts to customer rates; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital.

177

---

Eastern Energy Gas' historical and forecasted capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items, are as follows (in millions):

			Three-Month Periods												Annual
			Ended March 31,												Forecast
			2025						2026						2026
Natural gas transmission and storage			$	10					$	32					$	166
Other			45						60						455
Total			$	55					$	92					$	621

Natural gas transmission and storage primarily includes growth capital expenditures related to planned regulated projects. Other includes primarily nonregulated and routine capital expenditures for natural gas transmission, storage and LNG terminalling infrastructure needed to serve existing and expected demand.

Material Cash Requirements

As of March 31, 2026, there have been no material changes in cash requirements from the information provided in Item 7 of Eastern Energy Gas' Annual Report on Form 10-K for the year ended December 31, 2025.

Regulatory Matters

Eastern Energy Gas is subject to comprehensive regulation. Refer to "Regulatory Matters" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for discussion regarding Eastern Energy Gas' current regulatory matters.

Environmental Laws and Regulations

Eastern Energy Gas is subject to federal, state and local laws and regulations regarding air quality, climate change, emissions performance standards, water quality and other environmental matters that have the potential to impact its current and future operations. In addition to imposing continuing compliance obligations, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. These laws and regulations are administered by various federal, state and local agencies. Eastern Energy Gas believes it is in material compliance with all applicable laws and regulations, although many are subject to interpretation that may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and Eastern Energy Gas is unable to predict the impact of the changing laws and regulations on its operations and financial results.

Refer to "Environmental Laws and Regulations" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for additional information regarding environmental laws and regulations.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Consolidated Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, impairment of goodwill and long-lived assets and income taxes. For additional discussion of Eastern Energy Gas' critical accounting estimates, see Item 7 of Eastern Energy Gas' Annual Report on Form 10-K for the year ended December 31, 2025. There have been no significant changes in Eastern Energy Gas' assumptions regarding critical accounting estimates since December 31, 2025.

178

---

Eastern Gas Transmission and Storage, Inc. and its subsidiaries

Consolidated Financial Section

179

---

PART I

Item 1.Financial Statements

Report of Independent Registered Public Accounting Firm						181
Consolidated Balance Sheets						182
Consolidated Statements of Operations						184
Consolidated Statements of Comprehensive Income						185
Consolidated Statements of Changes in Shareholder's Equity						186
Consolidated Statements of Cash Flows						187
Notes to Consolidated Financial Statements
General						188
New Accounting Pronouncements						188
Property, Plant and Equipment, Net						188
Investments and Restricted Cash and Cash Equivalents						189
Income Taxes						190
Employee Benefit Plans						190
Fair Value Measurements						191
Commitments and Contingencies						192
Revenue from Contracts with Customers						193

180

---

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors of

Eastern Gas Transmission and Storage, Inc.

Results of Review of Interim Financial Information

We have reviewed the accompanying consolidated balance sheet of Eastern Gas Transmission and Storage, Inc. and subsidiaries ("EGTS") as of March 31, 2026, the related consolidated statements of operations, changes in shareholder's equity, and cash flows for the three-month periods ended March 31, 2026 and 2025, and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of EGTS as of December 31, 2025 and the related consolidated statements of operations, comprehensive income, changes in shareholder's equity, and cash flows for the year then ended (not presented herein); and in our report dated February 27, 2026 we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2025, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of EGTS' management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to EGTS in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/ Deloitte & Touche LLP

Richmond, Virginia

May 1, 2026

181

---

EASTERN GAS TRANSMISSION AND STORAGE, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions)

			As of
			March 31,						December 31,
			2026						2025
ASSETS
Current assets:
Cash and cash equivalents			$	27					$	10
Restricted cash and cash equivalents			28						29
Trade receivables, net			91						97
Receivables from affiliates			6						5
Notes receivable from affiliates			224						131
Inventories			60						58
Prepayments and other deferred charges			29						30
Natural gas imbalances			62						73
Other current assets			17						24
Total current assets			544						457
Property, plant and equipment, net			4,961						4,909
Other assets			61						61
Total assets			$	5,566					$	5,427

The accompanying notes are an integral part of these consolidated financial statements.

182

---

EASTERN GAS TRANSMISSION AND STORAGE, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited) (continued)

(Amounts in millions, except share data)

			As of
			March 31,						December 31,
			2026						2025
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities:
Accounts payable			$	61					$	57
Accounts payable to affiliates			19						20
Accrued interest			24						7
Accrued property, income and other taxes			82						75
Accrued employee expenses			23						19
Regulatory liabilities			20						19
Customer deposits			28						29
Other current liabilities			24						26
Total current liabilities			281						252
Long-term debt			1,624						1,623
Regulatory liabilities			509						514
Deferred income taxes			187						167
Other long-term liabilities			76						77
Total liabilities			2,677						2,633
Commitments and contingencies (Note 8)
Shareholder's equity:
Common stock - 75,000 shares authorized, $10,000 par value, 60,101 issued and outstanding			609						609
Additional paid-in capital			1,380						1,380
Retained earnings			923						829
Accumulated other comprehensive loss, net			(23)						(24)
Total shareholder's equity			2,889						2,794
Total liabilities and shareholder's equity			$	5,566					$	5,427

The accompanying notes are an integral part of these consolidated financial statements.

183

---

EASTERN GAS TRANSMISSION AND STORAGE, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Operating revenue			$	289					$	275
Operating expenses:
Cost of gas			1						—
Operations and maintenance			81						89
Depreciation and amortization			41						40
Property and other taxes			15						14
Total operating expenses			138						143
Operating income			151						132
Other income (expense):
Interest expense, net			(17)						(18)
Allowance for equity funds			3						2
Other, net			3						1
Total other income (expense)			(11)						(15)
Income before income tax expense (benefit)			140						117
Income tax expense (benefit)			34						29
Net income			$	106					$	88

The accompanying notes are an integral part of these consolidated financial statements.

184

---

EASTERN GAS TRANSMISSION AND STORAGE, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Net income			$	106					$	88
Other comprehensive income, net of tax:
Unrealized gains on cash flow hedges, net of tax of $— and $—			1						—
Total other comprehensive income, net of tax			1						—
Comprehensive income			$	107					$	88

The accompanying notes are an integral part of these consolidated financial statements.

185

---

EASTERN GAS TRANSMISSION AND STORAGE, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY (Unaudited)

(Amounts in millions, except shares)

																											Accumulated
															Additional												Other						Total
			Common Stock												Paid-in						Retained						Comprehensive						Shareholder's
			Shares						Amount						Capital						Earnings						Loss, Net						Equity
Balance, December 31, 2024			60,101						$	609					$	1,352					$	671					$	(26)					$	2,606
Net income			—						—						—						88						—						88
Balance, March 31, 2025			60,101						$	609					$	1,352					$	759					$	(26)					$	2,694
Balance, December 31, 2025			60,101						$	609					$	1,380					$	829					$	(24)					$	2,794
Net income			—						—						—						106						—						106
Other comprehensive income			—						—						—						—						1						1
Dividends declared			—						—						—						(12)						—						(12)
Balance, March 31, 2026			60,101						$	609					$	1,380					$	923					$	(23)					$	2,889

The accompanying notes are an integral part of these consolidated financial statements.

186

---

EASTERN GAS TRANSMISSION AND STORAGE, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

			Three-Month Periods
			Ended March 31,
			2026						2025
Cash flows from operating activities:
Net income			$	106					$	88
Adjustments to reconcile net income to net cash flows from operating activities:
Gains on other items, net			(16)						—
Depreciation and amortization			41						40
Allowance for equity funds			(3)						(2)
Changes in regulatory assets and liabilities			2						(13)
Deferred income taxes			19						17
Other, net			1						1
Changes in other operating assets and liabilities:
Trade receivables and other assets			12						8
Receivables from affiliates			(1)						(4)
Gas balancing activities			(6)						12
Accrued property, income and other taxes			(1)						(4)
Accounts payable to affiliates			(1)						—
Accounts payable and other liabilities			24						6
Net cash flows from operating activities			177						149
Cash flows from investing activities:
Capital expenditures			(75)						(41)
Proceeds from assignment of shale development rights			16						—
Proceeds from sales of marketable securities			3						7
Issuance of notes receivable to affiliates			(105)						—
Repayment of notes receivable by affiliates			12						—
Net cash flows from investing activities			(149)						(34)
Cash flows from financing activities:
Dividends paid			(12)						—
Net cash flows from financing activities			(12)						—
Net change in cash and cash equivalents and restricted cash and cash equivalents			16						115
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period			39						32
Cash and cash equivalents and restricted cash and cash equivalents at end of period			$	55					$	147

The accompanying notes are an integral part of these consolidated financial statements.

187

---

EASTERN GAS TRANSMISSION AND STORAGE, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    General

Eastern Gas Transmission and Storage, Inc. and its subsidiaries ("EGTS") conduct business activities consisting of Federal Energy Regulatory Commission ("FERC")-regulated interstate natural gas transmission systems and underground storage. EGTS' operations include transmission assets located in Maryland, New York, Ohio, Pennsylvania, Virginia and West Virginia. EGTS also operates one of the nation's largest underground natural gas storage systems located in New York, Pennsylvania and West Virginia. EGTS is a wholly owned subsidiary of Eastern Energy Gas Holdings, LLC ("Eastern Energy Gas"), which is an indirect wholly owned subsidiary of Berkshire Hathaway Energy Company ("BHE"). BHE is a holding company headquartered in Des Moines, Iowa that has investments in subsidiaries principally engaged in energy businesses. BHE is a wholly owned subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The accompanying Consolidated Financial Statements and Notes to Consolidated Financial Statements should be read in conjunction with EGTS' Annual Report on Form 10-K for the year ended December 31, 2025. The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2026, and for the three-month periods ended March 31, 2026 and 2025. The results of operations for the three-month period ended March 31, 2026, are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in EGTS' Annual Report on Form 10-K for the year ended December 31, 2025, describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in EGTS' accounting policies or its assumptions regarding significant accounting estimates during the three-month period ended March 31, 2026.

Segment Information

EGTS currently has one reportable segment, which includes its natural gas transmission and storage operations. EGTS' chief operating decision maker ("CODM") is the President and Chief Executive Officer of the BHE Pipeline Group (which consists primarily of BHE GT&S, LLC, Northern Natural Gas Company and Kern River Gas Transmission Company). Net income, as reported on the Consolidated Statements of Operations, is considered by the CODM in allocating resources and capital. When making decisions about the allocation of resources and capital, the CODM generally considers actual results versus historical results, budgets or forecast, as well as unique risks and opportunities. The segment expense information regularly provided to the CODM aligns with the captions presented on the Consolidated Statements of Operations. The measure of segment assets is reported on the Consolidated Balance Sheets as total assets.

(2)    New Accounting Pronouncements

In November 2024, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures Subtopic 220-40, "Disaggregation of Income Statement Expenses" which addresses requests from investors for more detailed information about certain expenses and requires disclosure of the amounts of purchases of inventory, employee compensation, depreciation and intangible asset amortization included in each relevant expense caption presented on the income statement. This guidance, as clarified in ASU 2025-01, is effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. Early adoption is permitted and should be applied on a prospective basis, however retrospective application is permitted. EGTS is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

188

---

(3)    Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

									As of
									March 31,						December 31,
			Depreciable Life						2026						2025
Interstate natural gas transmission assets			47 - 51 years						$	5,271					$	5,213
Storage assets			47 - 51 years						1,896						1,884
Intangible plant and other assets			12 - 53 years						420						408
Plant in-service									7,587						7,505
Accumulated depreciation and amortization									(2,862)						(2,824)
									4,725						4,681
Construction work-in-progress									236						228
Property, plant and equipment, net									$	4,961					$	4,909

Assignment of Shale Development Rights

In September 2025, EGTS signed an agreement to convey development rights over time to a natural gas producer for approximately 23,000 acres of Utica Shale and Point Pleasant formations underneath one of its natural gas storage fields. The agreement provides for payments to EGTS of approximately $49 million over a period of three years, and an overriding royalty interest in gas produced from the acreage. In January 2026, EGTS conveyed approximately 7,600 acres and received proceeds of $16 million from the initial conveyance. This transaction resulted in a $16 million ($12 million after-tax) gain recorded in operations and maintenance expense in its Consolidated Statements of Operations.

(4)    Investments and Restricted Cash and Cash Equivalents

Investments and restricted cash and cash equivalents consists of the following (in millions):

			As of
			March 31,						December 31,
			2026						2025
Investments:
Investment funds			$	5					$	8
Restricted cash and cash equivalents:
Customer deposits			28						29
Total investments and restricted cash and cash equivalents			$	33					$	37
Reflected as:
Current assets			$	28					$	29
Other assets			5						8
Total investments and restricted cash and cash equivalents			$	33					$	37

189

---

Cash and Cash Equivalents and Restricted Cash and Cash Equivalents

Cash equivalents consist of funds invested in money market mutual funds, U.S. Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted cash and cash equivalents consist of customer deposits as allowed under the FERC gas tariff. A reconciliation of cash and cash equivalents and restricted cash and cash equivalents as presented on the Consolidated Statements of Cash Flows is outlined below and disaggregated by the line items in which they appear on the Consolidated Balance Sheets (in millions):

			As of
			March 31,						December 31,
			2026						2025
Cash and cash equivalents			$	27					$	10
Restricted cash and cash equivalents			28						29
Total cash and cash equivalents and restricted cash and cash equivalents			$	55					$	39

(5)    Income Taxes

Berkshire Hathaway includes BHE and its subsidiaries in its U.S. federal income tax return and BHE includes its subsidiaries in certain state income tax returns. Consistent with established regulatory practice, EGTS' provision for federal and state income tax has been computed on a stand-alone basis, and substantially all of its currently payable or receivable income tax is remitted to or received from BHE pursuant to a tax allocation agreement. For current federal and state income taxes, EGTS had a payable to BHE of $22 million and $11 million as of March 31, 2026 and December 31, 2025, respectively.

A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income before income tax expense (benefit) is as follows (amounts in millions):

			Three-Month Periods
			Ended March 31,
			2026												2025
			Amount						Percent						Amount						Percent
U.S. federal statutory income tax rate			$	29					21.0		%				$	24					21.0		%
State and local income taxes, net of federal income tax			5						3.3						5						3.8
Effective income tax rate			$	34					24.3		%				$	29					24.8		%

(6)    Employee Benefit Plans

EGTS is a participant in benefit plans sponsored by MidAmerican Energy Company ("MidAmerican Energy"), an affiliate. The MidAmerican Energy Company Retirement Plan includes a qualified pension plan that provides pension benefits for eligible employees. The MidAmerican Energy Company Welfare Benefit Plan provides certain postretirement health care and life insurance benefits for eligible retirees on behalf of EGTS. EGTS contributed $1 million to the MidAmerican Energy Company Retirement Plan for each of the three-month periods ended March 31, 2026 and 2025. Contributions related to these plans are reflected as net periodic benefit cost in operations and maintenance expense on the Consolidated Statements of Operations. Amounts attributable to EGTS were allocated from MidAmerican Energy in accordance with the intercompany administrative service agreement. Offsetting regulatory assets and liabilities have been recorded related to the amounts not yet recognized as a component of net periodic benefit costs that will be included in regulated rates. As of March 31, 2026, and December 31, 2025, EGTS' amount due to MidAmerican Energy associated with these plans and included in other long-term liabilities on the Consolidated Balance Sheets was $35 million.

190

---

(7)    Fair Value Measurements

The carrying value of EGTS' cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. EGTS has various financial assets and liabilities that are measured at fair value on the Consolidated Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

•Level 1 — Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that EGTS has the ability to access at the measurement date.

•Level 2 — Inputs include 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 that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).

•Level 3 — Unobservable inputs reflect EGTS' judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. EGTS develops these inputs based on the best information available, including its own data.

The following table presents EGTS' financial assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions):

						Input Levels for Fair Value Measurements
						Level 1						Level 2						Level 3						Total
As of March 31, 2026:
Assets:
Money market mutual funds						$	27					$	—					$	—					$	27
Equity securities:
Investment funds						5						—						—						5
						$	32					$	—					$	—					$	32
As of December 31, 2025:
Assets:
Money market mutual funds						$	10					$	—					$	—					$	10
Equity securities:
Investment funds						8						—						—						8
						$	18					$	—					$	—					$	18

EGTS' investments in money market mutual funds and investment funds are stated at fair value. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value.

191

---

Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchase or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which EGTS transacts. When quoted prices for identical contracts are not available, EGTS uses forward price curves. Forward price curves represent EGTS' estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. EGTS bases its forward price curves upon market price quotations, when available, or internally developed and commercial models, with internal and external fundamental data inputs. Market price quotations are obtained from independent brokers, exchanges, direct communication with market participants and actual transactions executed by EGTS. Market price quotations are generally readily obtainable for the applicable term of EGTS' outstanding derivative contracts; therefore, EGTS' forward price curves reflect observable market quotes. Market price quotations for certain natural gas trading hubs are not as readily obtainable due to the length of the contracts. Given that limited market data exists for these contracts, as well as for those contracts that are not actively traded, EGTS uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The estimated fair value of these derivative contracts is a function of underlying forward commodity prices, related volatility, counterparty creditworthiness and duration of contracts.

EGTS' long-term debt is carried at cost on the Consolidated Financial Statements. The fair value of EGTS' long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The following table presents the carrying value and estimated fair value of EGTS' long-term debt (in millions):

			As of March 31, 2026												As of December 31, 2025
			Carrying Value						Fair Value						Carrying Value						Fair Value
Long-term debt			$	1,624					$	1,429					$	1,623					$	1,442

(8)    Commitments and Contingencies

Environmental Laws and Regulations

EGTS is subject to federal, state and local laws and regulations regarding air quality, climate change, emissions performance standards, water quality and other environmental matters that have the potential to impact its current and future operations. EGTS believes it is in material compliance with all applicable laws and regulations.

Legal Matters

EGTS is party to a variety of legal actions arising out of the normal course of business. EGTS does not believe that such normal and routine litigation will have a material impact on its consolidated financial results.

192

---

(9)    Revenue from Contracts with Customers

The following table summarizes EGTS' revenue from contracts with customers ("Customer Revenue") by regulated and other, with further disaggregation of regulated by line of business (in millions):

			Three-Month Periods
			Ended March 31,
			2026						2025
Customer Revenue:
Regulated:
Gas transmission			$	195					$	190
Gas storage			71						71
Wholesale			2						1
Total regulated			268						262
Management service and other revenues			15						12
Total Customer Revenue			283						274
Other revenue(1)			6						1
Total operating revenue			$	289					$	275

(1)Other revenue consists primarily of revenue recognized in accordance with Accounting Standards Codification 815, "Derivative and Hedging" which includes unrealized gains and losses for derivatives not designated as hedges related to natural gas sales contracts, contingent fees from certain farmout agreements recognized in accordance with ASC 450, "Contingencies" and the royalties from the conveyance of mineral rights accounted for under Accounting Standards Codification 932, "Extractive Activities – Oil and Gas".

Remaining Performance Obligations

The following table summarizes EGTS' revenue it expects to recognize in future periods related to significant unsatisfied remaining performance obligations for fixed contracts with expected durations in excess of one year as of March 31, 2026 (in millions):

			Performance obligations expected to be satisfied:
			Less than 12 months						More than 12 months						Total
EGTS			$	838					$	2,890					$	3,728

193

---

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

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of EGTS during the periods included herein. This discussion should be read in conjunction with EGTS' historical Consolidated Financial Statements and Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q. EGTS' actual results in the future could differ significantly from the historical results.

Results of Operations for the First Quarter of 2026 and 2025

Overview

Net income for the first quarter of 2026 was $106 million, an increase of $18 million compared to 2025. Net income increased primarily due to a gain from an agreement to convey development rights underneath one of its natural gas storage fields and higher margin from regulated gas transmission and storage operations of $13 million.

Quarter Ended March 31, 2026, Compared to Quarter Ended March 31, 2025

Operating revenue increased $14 million, or 5%, for the first quarter of 2026 compared to 2025, primarily due to an increase in royalties and other contingent fees from farmout agreements of $5 million, an increase in variable revenue related to park and loan activity of $4 million, an increase in regulated gas transmission and storage services revenues primarily due to additional capacity contracts of $2 million and an increase in services provided to affiliates of $2 million.

Operations and maintenance decreased $8 million, or 9%, for the first quarter of 2026 compared to 2025, primarily due to a gain from an agreement to convey development rights underneath one of its natural gas storage fields of $16 million, partially offset by higher employee costs of $3 million, an increase in services provided to affiliates of $2 million and an increase in charges from affiliates of $2 million.

Income tax expense increased $5 million, or 17%, for the first quarter of 2026 compared to 2025. The effective tax rate was 24% and 25% for the three-month periods ended March 31, 2026 and 2025, respectively. The $5 million increase was primarily due to higher pre-tax income.

Liquidity and Capital Resources

As of March 31, 2026, EGTS' total net liquidity was as follows (in millions):

Cash and cash equivalents						$	27
Intercompany revolving credit agreement, maturing 2027						400
Total net liquidity						$	427

Operating Activities

Net cash flows from operating activities for the three-month periods ended March 31, 2026 and 2025 were $177 million and $149 million, respectively. The change is primarily due to higher collections from customers, the timing of payments for operating costs and other working capital adjustments.

Investing Activities

Net cash flows from investing activities for the three-month periods ended March 31, 2026 and 2025 were $(149) million and $(34) million, respectively. The change is primarily due to an increase in notes issued to Eastern Energy Gas under an intercompany revolving credit agreement of $105 million, an increase in capital expenditures of $34 million and a decrease in proceeds from sales of marketable securities of $4 million, partially offset by proceeds from the assignment of shale development rights of $16 million and an increase in repayments of notes by Eastern Energy Gas under an intercompany revolving credit agreement of $12 million.

194

---

Financing Activities

Net cash flows from financing activities for the three-month period ended March 31, 2026 were $(12) million and consisted of dividends paid to Eastern Energy Gas.

Future Uses of Cash

EGTS has available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, intercompany revolving credit agreements, capital contributions and other sources. These sources are expected to provide funds required for current operations, capital expenditures, investments, debt retirements and other capital requirements. The availability and terms under which EGTS has access to external financing depends on a variety of factors, including regulatory approvals, EGTS' credit ratings, investors' judgment of risk and conditions in the overall capital markets, including the condition of the natural gas transmission and storage industry.

Capital Expenditures

Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, new growth projects and the timing of growth projects; changes in environmental and other rules and regulations; impacts to customer rates; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital.

EGTS' historical and forecasted capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items, are as follows (in millions):

			Three-Month Periods												Annual
			Ended March 31,												Forecast
			2025						2026						2026
Natural gas transmission and storage			$	8					$	31					$	163
Other			33						44						372
Total			$	41					$	75					$	535

Natural gas transmission and storage includes primarily growth capital expenditures related to planned regulated projects. Other includes primarily pipeline integrity work, automation and controls upgrades, underground storage, corrosion control, unit exchanges, compressor modifications and projects related to Pipeline Hazardous Materials Safety Administration natural gas storage rules. The amounts also include EGTS' asset modernization program, which includes projects for vintage pipeline replacement, compression replacement, pipeline assessment and underground storage integrity.

Material Cash Requirements

As of March 31, 2026, there have been no material changes in cash requirements from the information provided in Item 7 of EGTS' Annual Report on Form 10-K for the year ended December 31, 2025.

Regulatory Matters

EGTS is subject to comprehensive regulation. Refer to "Regulatory Matters" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for discussion regarding EGTS' current regulatory matters.

195

---

Environmental Laws and Regulations

EGTS is subject to federal, state and local laws and regulations regarding air quality, climate change, emissions performance standards, water quality and other environmental matters that have the potential to impact its current and future operations. In addition to imposing continuing compliance obligations, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance, including fines, injunctive relief and other sanctions. These laws and regulations are administered by various federal, state and local agencies. EGTS believes it is in material compliance with all applicable laws and regulations, although many are subject to interpretation that may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and EGTS is unable to predict the impact of the changing laws and regulations on its operations and financial results.

Refer to "Environmental Laws and Regulations" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for additional information regarding environmental laws and regulations.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Consolidated Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, impairment of long-lived assets and income taxes. For additional discussion of EGTS' critical accounting estimates, see Item 7 of EGTS' Annual Report on Form 10-K for the year ended December 31, 2025. There have been no significant changes in EGTS' assumptions regarding critical accounting estimates since December 31, 2025.

196

---

Item 3.Quantitative and Qualitative Disclosures About Market Risk

For quantitative and qualitative disclosures about market risk affecting the Registrants, see Item 7A of each Registrant's Annual Report on Form 10-K for the year ended December 31, 2025. Each Registrant's exposure to market risk and its management of such risk has not changed materially since December 31, 2025. Refer to Note 9 of the Notes to Consolidated Financial Statements of PacifiCorp, Note 8 of the Notes to Consolidated Financial Statements of Nevada Power and Note 8 of the Notes to Consolidated Financial Statements of Sierra Pacific in Part I, Item 1 of this Form 10-Q for disclosure of the respective Registrant's derivative positions as of March 31, 2026.

Item 4.Controls and Procedures

At the end of the period covered by this Quarterly Report on Form 10-Q, each of Berkshire Hathaway Energy Company, PacifiCorp, MidAmerican Funding, LLC, MidAmerican Energy Company, Nevada Power Company, Sierra Pacific Power Company, Eastern Energy Gas Holdings, LLC and Eastern Gas Transmission and Storage, Inc. carried out separate evaluations, under the supervision and with the participation of each such entity's management, including its Chief Executive Officer (principal executive officer) and its Chief Financial Officer (principal financial officer), or persons performing similar functions, of the effectiveness of the design and operation of its disclosure controls and procedures (as defined in Rule 13a-15(e) promulgated under the Securities Exchange Act of 1934, as amended). Based upon these evaluations, management of each such entity, including its Chief Executive Officer (principal executive officer) and its Chief Financial Officer (principal financial officer), or persons performing similar functions, in each case, concluded that the disclosure controls and procedures for such entity were effective to ensure that information required to be disclosed by such entity in the reports that it files or submits under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the time periods specified in the United States Securities and Exchange Commission's rules and forms, and is accumulated and communicated to its management, including its Chief Executive Officer (principal executive officer) and its Chief Financial Officer (principal financial officer), or persons performing similar functions, in each case, as appropriate to allow timely decisions regarding required disclosure by it. Each such entity hereby states that there has been no change in its internal control over financial reporting during the quarter ended March 31, 2026, that has materially affected, or is reasonably likely to materially affect, its internal control over financial reporting.

197

---

PART II

Item 1.Legal Proceedings

The following disclosures reflect material updates to legal proceedings and should be read in conjunction with Item 3 of Berkshire Hathaway Energy's and PacifiCorp's Annual Reports on Form 10-K for the year ended December 31, 2025.

BERKSHIRE HATHAWAY ENERGY AND PACIFICORP

In September 2020, a severe weather event with high winds contributed to several major wildfires, including the 2020 Wildfires, resulting in real and personal property and natural resource damage, personal injuries and loss of life and widespread power outages in Oregon and Northern California. The wildfires spread across certain parts of PacifiCorp's service territory and surrounding areas across multiple counties in Oregon and California, burning over 500,000 acres in aggregate. Third-party reports for these wildfires indicate over 2,000 structures destroyed, including residences; several structures damaged; multiple individuals injured; and several fatalities.

In July 2022, the 2022 McKinney Fire began in Siskiyou County, California, within PacifiCorp's service territory, burning over 60,000 acres. Third-party reports indicate that the 2022 McKinney Fire resulted in 11 structures damaged; 185 structures destroyed, including residences; 12 injuries; and four fatalities.

As described below, a significant number of complaints and demands alleging similar claims related to the Wildfires have been filed in Oregon and California, including the James class action complaint in Oregon associated with 2020 Wildfires for which certain jury verdicts were issued as described below. The James case is the most significant remaining litigation related to the Wildfires and concerns four Oregon fires hundreds of miles apart: the Beachie Creek Fire (which spread into the Santiam Canyon), the Echo Mountain Complex Fire, the South Obenchain Fire, and the 242 Fire.

The following map illustrates the general vicinity of the Wildfires.

198

---

Substantially all amounts sought in outstanding complaints and demands filed in Oregon are associated with the James mass complaints described below, as well as stayed cases for which motions have been filed for consolidation into the James case and the state of Oregon demands. Many Oregon complaints seek doubled or trebled damages based on relevant provisions of Oregon law.

Investigations

Both the U.S. Department of Agriculture Forest Service ("USFS") and the Oregon Department of Forestry ("ODF") completed investigation reports related to the Beachie Creek Fire that was first reported outside the Santiam Canyon on August 16, 2020, approximately three weeks before the severe weather event described above. The ODF's report concerning the Beachie Creek Fire concluded that embers from the pre-existing Beachie Creek Fire caused 12 fires within the Santiam Canyon. The ODF's report also found that PacifiCorp's power lines did not contribute to the overall spread of fire into the Santiam Canyon even though PacifiCorp's power lines ignited seven spot fires within the Santiam Canyon that were each suppressed.

Wildfire Settlements

PacifiCorp has settled various claims associated with the Wildfires as described below and has settled all wrongful death claims and federal government demands and complaints associated with the Wildfires. For the Archie Creek Fire, Slater Fire and 2022 McKinney Fire, settlements have been reached with substantially all plaintiffs. For the Santiam Canyon, Echo Mountain Complex, South Obenchain and 242 fires, while PacifiCorp settled claims with individual plaintiffs who were granted substitution of counsel in the James case, with the Oregon wineries and with the federal government as described below, claims remain outstanding for a substantial number of plaintiffs associated with the James case.

2020 Wildfires

As of the date of this filing, PacifiCorp has made settlement payments associated with individual plaintiffs, wrongful death claims, insurance subrogation claims, commercial timber claims and certain government claims associated with the 2020 Wildfires totaling $2,012 million, including $609 million associated with the James related fires for plaintiffs who opted out of the James class, plaintiffs granted substitution counsel in the James case, Oregon wineries, insurance subrogation claims and for plaintiffs in certain of the James consolidated cases and $535 million associated with the federal government demands settled in February 2026. For more information, refer to description of the 2020 Wildfires complaints and specific wildfires below.

2022 McKinney Fire

As of the date of this filing, PacifiCorp has made settlement payments associated with individual plaintiffs, wrongful death claims, insurance subrogation claims, commercial timber claims, private timber claims and certain government claims associated with the 2022 McKinney Fire totaling $268 million, including $40 million associated with the federal government demands settled in February 2026. For more information, refer to description of the 2022 McKinney Fire complaints below.

2020 Oregon Wildfires, Excluding the Northern California and Southern Oregon Slater Fire ("Slater Fire")

A significant number of complaints on behalf of plaintiffs associated with the 2020 Wildfires were filed in Oregon. Although many of these complaints have been resolved and dismissed, a significant portion remain outstanding relating to the James case as described below. The plaintiffs generally allege: (i) negligence due in part to alleged failure to comply with certain Oregon statutes and administrative rules, including those issued by the OPUC; (ii) gross negligence alleged in the form of willful, wanton and reckless disregard of known risks to the public; (iii) trespass; (iv) nuisance; (v) inverse condemnation; (vi) pre- and post-judgment interest; and (vii) reasonable attorney fees, investigation costs and expert witness fees. The complaints generally assert claims for: (i) noneconomic damages, including mental suffering, emotional distress, inconvenience and interference with normal and usual activities; (ii) damages for real and personal property and other economic losses; (iii) double the amount of property and economic damages; (iv) treble damages for specific costs associated with loss of forestry, trees and shrubbery; and (v) double the amount of damages for the costs of litigation and reforestation. The plaintiffs generally demand a trial by jury and reserve their right to further amend their complaints to allege claims for punitive damages.

199

---

The James Case

On September 30, 2020, a class action complaint against PacifiCorp captioned Jeanyne James et al. v. PacifiCorp, ("James") was filed in Oregon Circuit Court in Multnomah County, Oregon ("Multnomah County Circuit Court Oregon"). The complaint was filed by Oregon residents and businesses who sought to represent a class of all Oregon citizens and entities whose real or personal property was harmed beginning on September 7, 2020, by wildfires in Oregon allegedly caused by PacifiCorp. In November 2021, the plaintiffs filed an amended complaint to limit the class to include Oregon citizens allegedly impacted by the Santiam Canyon, Echo Mountain Complex, South Obenchain and 242 fires, as well as to add claims for noneconomic damages. The amended complaint alleged that PacifiCorp's assets contributed to the Oregon wildfires occurring on or after September 7, 2020, and that PacifiCorp acted with gross negligence, among other things. The amended complaint seeks damages similar to those described above, including not less than $600 million of economic damages and in excess of $1 billion of noneconomic damages for the plaintiffs and the class. Since the filing of the original class action complaint, several cases have been stayed pending consolidation into James and numerous James class members have been named and damaged specified in various complaints as described below under "James Consolidated Cases."

The Multnomah County Circuit Court Oregon determined that the James case would be divided into a liability phase ("Phase I") and a damages phase ("Phase II"). In June 2023, a jury in the Phase I liability trial found PacifiCorp's conduct grossly negligent, reckless and willful as to each of the 17 named plaintiffs and the entire class. The jury awarded economic and noneconomic damages, as well as punitive damages. After the jury verdict, the Multnomah County Circuit Court Oregon doubled the Phase I plaintiffs' economic damages, in accordance with Oregon law, and added punitive damages by applying a 0.25 multiplier to the awarded economic and noneconomic damages. The Multnomah County Circuit Court Oregon granted PacifiCorp's subsequent motion to offset the damage awards by deducting insurance proceeds received by any of the plaintiffs.

PacifiCorp subsequently appealed the Phase I liability verdict, and on April 8, 2026, the verdict was reversed and remanded by the Oregon Court of Appeals, as described in more detail below. In the interim, however, James class members filed mass damages complaints premised on the Phase I liability verdict. In April, May, July and September 2024; January, May and September 2025; and January 2026, nine separate mass complaints against PacifiCorp naming 1,000, 100, 265, 78, 93, 55, 99, 34 and 36 individual class members, respectively, were filed in Multnomah County Circuit Court Oregon captioned Shane A Henson et al. v. PacifiCorp, Karen Andersen et al. v. PacifiCorp, Vanessa Alexander et al. v. PacifiCorp, Emily Broderick et al. v. PacifiCorp, Sergio Garcia Montes et al. v. PacifiCorp, Butte Falls Family Ranch, LLC et al. v. PacifiCorp, Amanda Bateman et al. v. PacifiCorp, Philip Estes et al. v. PacifiCorp and Stephen Becker et al. v. PacifiCorp, respectively, each referencing the original James case as the lead case. The James mass complaints make damages-only allegations seeking for each individual class member $5 million of economic damages, $25 million of noneconomic damages and punitive damages equal to 0.25 times the amount of economic and noneconomic damages, as well as doubling of economic damages. Complaints for some of the plaintiffs in the mass complaints have been dismissed, amended or re-filed.

While PacifiCorp's appeal of the Phase I verdict was pending, the Multnomah County Circuit Court Oregon held numerous Phase II trials, in which a series of juries awarded damages to groups of James class members. The majority of these trials were scheduled pursuant to a case management order called "CMO No. 11." PacifiCorp has filed notices of appeal for the subsequent jury verdicts in the Phase II trials once limited judgments are entered and any post-trial motions filed. The James jury verdicts to date have awarded total net damages of $1,252 million to 201 plaintiffs, including $133 million of doubled economic damages, $910 million of noneconomic damages, $244 million of punitive damages and partially offset by estimated insurance offsets of $35 million. To date, PacifiCorp has been required to bond the amounts awarded by the James limited judgments in order to stay payment of damages while on appeal. As of the date of this filing, PacifiCorp has posted bonds totaling $719 million associated with the limited judgments entered to date for 129 plaintiffs. Based on the April 2026 Oregon Court of Appeals opinion, the existing bonds could eventually be discharged and any future bonding requirements eliminated.

The Oregon Court of Appeals' April 2026 opinion reversing the Phase I verdict explained that the Multnomah County Circuit Court Oregon erred in instructing the jury that they could "assume that the evidence at the trial applies to all class members." The Oregon Court of Appeals further concluded that the erroneous jury instruction "was prejudicial to PacifiCorp" because it "gave rise to some likelihood that the jury reached an erroneous result." Because the Oregon Court of Appeals reversed and remanded on the instructional error issue presented in PacifiCorp's appellate brief, it did not address the majority of PacifiCorp's other appealed issues. However, the Oregon Court of Appeals emphasized that the Multnomah County Circuit Court Oregon has the authority on remand to reconsider its class certification decision and reconsider whether a single class is appropriate in this case. The Oregon Court of Appeals determined PacifiCorp was the prevailing party and awarded costs to PacifiCorp. Either party can file a petition for review with the Oregon Supreme Court within 35 days of the Oregon Court of Appeals opinion, subject to extension. Whether the Oregon Supreme Court accepts a request for review is at its discretion.

200

---

On April 9, 2026, the Multnomah County Circuit Court Oregon ordered a stay of scheduled James Phase II trials (except for a trial that began April 6, 2026, and subsequently concluded on April 13, 2026) and mandatory mediation. The Multnomah County Circuit Court Oregon asked the parties to submit briefing on the merits, scope and duration of the stay in advance of a May 22, 2026, hearing.

James Consolidated Cases

The following cases have been stayed pending consolidation into the original James case:

The amended Salter complaint was filed August 20, 2021, in Multnomah County Circuit Court Oregon by approximately 97 individuals seeking damages similar to those described above, including economic damages not to exceed $150 million and noneconomic damages not to exceed $500 million. A portion of these plaintiffs are included in the James mass complaints and either already have verdicts or had trials scheduled under CMO No. 11 (before the recent stay). The Salter case is currently stayed due to plaintiffs' motion to consolidate the case into James.

The amended Allen complaint was filed September 2, 2021, in Multnomah County Circuit Court Oregon by approximately five individuals seeking damages similar to those described above, including $8 million in economic damages and $24 million in noneconomic damages related to the Beachie Creek Fire. All five of these plaintiffs are included in the James mass complaints and either already have verdicts or had trials scheduled under CMO No. 11 (before the recent stay). The Allen case is currently stayed due to plaintiffs' motion to consolidate the case into James.

The amended Dietrich complaint was filed September 6, 2022, in Multnomah County Circuit Court Oregon by six Oregon residents individually and on behalf of a proposed class defined to include residents of, business owners in, real or personal property owners in and any other individuals physically present in specified Oregon counties as of September 7, 2020 who experienced any harm, damage or loss as a result of the Santiam Canyon, Echo Mountain Complex, 242 or South Obenchain fires. The amended complaint seeks $400 million in economic damages and $500 million in noneconomic damages on behalf of the proposed class. The Dietrich case is currently stayed due to plaintiffs' motion to consolidate the case into James.

The Bell complaint was filed September 7, 2022, in Multnomah County Circuit Court Oregon by 59 plaintiffs seeking $35 million in damages, including economic and noneconomic damages. A portion of these plaintiffs had trials scheduled under CMO No. 11 (before the recent stay). The Bell case is currently stayed due to plaintiffs' motion to consolidate the case into James.

Ashley Andersen et al. v. PacifiCorp and Consolidated Cases

As a result of settlements reached in 2024 for the Andersen et al. v. PacifiCorp consolidated cases, the complaints have been resolved but for one remaining plaintiff from the consolidated Weathers complaint. The Weathers complaint was filed September 1, 2022, in Multnomah County Circuit Court Oregon by approximately 46 plaintiffs seeking damages associated with the Echo Mountain Complex fires, including economic damages of approximately $83 million and noneconomic damages of approximately $83 million.

Other Cases

Several other complaints were filed against PacifiCorp associated with the 2020 Wildfires for which several settlements were reached as described above. However, certain complaints remain outstanding as described below.

In March 2026, notice of dismissal was filed for the Lexington and Ace American Insurance Co. complaints as a result of the Rock Creek Fish Hatchery settlement described below under "State of Oregon – Loss and Damages to State Lands – Oregon Fires." These complaints were filed against PacifiCorp in Douglas County Circuit Court Oregon in 2022 and were previously partially dismissed following settlement with subrogation insurers across 2022, 2023 and early 2024.

201

---

State of Oregon – Loss and Damages to State Lands – Oregon Fires

In 2023, PacifiCorp also received correspondence from the Oregon Department of Justice ("ODOJ"), representing the State of Oregon, regarding the potential recovery of losses and damages to state lands from the Archie Creek and Susan Creek fires. The ODOJ provided a damage estimate of approximately $109 million for mediation purposes only, which included losses and damages relating to the sheltering of, and assistance to, affected Oregonians; fire control and extinguishment costs; timber damage across 39 acres of Oregon forestland; losses and damages at the Rock Creek Fish Hatchery; road and highway damages; and other costs. In November 2025, PacifiCorp reached settlement for the Rock Creek Fish Hatchery component of this matter.

On February 19, 2025, PacifiCorp received a demand from the ODF for $2 million in fire suppression costs incurred by the ODF associated with the Oregon portion of the Slater Fire.

On April 4, 2025, PacifiCorp received a demand from the ODF for $11 million in fire suppression costs associated with the South Obenchain fire.

On April 21, 2025, PacifiCorp received a demand from the ODF for $4 million in fire suppression costs associated with the Echo Mountain and Kimberling Mountain fires.

On May 5, 2025, PacifiCorp received a demand from the Oregon State Fire Marshal for $5 million in fire suppression costs associated with the Slater Fire.

PacifiCorp is actively cooperating with the ODOJ on resolving the alleged claims.

2022 McKinney Fire

Numerous complaints associated with the 2022 McKinney Fire were filed in Sacramento County Superior Court California on behalf of approximately 1,200 plaintiffs as described below. Certain complaints included wrongful death claims associated with four fatalities. The complaints generally allege: (i) inverse condemnation; (ii) negligence; (iii) trespass; (iv) nuisance; and (v) violation of certain sections of the California Public Utilities Code and the California Health & Safety Code and seek various damages. The damages sought generally include: (i) economic damages; (ii) noneconomic damages; (iii) doubling or trebling of timber damages; (iv) punitive damages; (v) prejudgment interest; and (vi) attorneys' fees and other costs. The complaints do not specify the amount of damages sought.

On August 16, 2022, a complaint against PacifiCorp was filed, captioned Bridges et al. v. PacifiCorp, ("Bridges") in Sacramento County Superior Court California by approximately five plaintiffs. Additional complaints associated with the 2022 McKinney Fire were filed and subsequently consolidated into the Bridges case, covering approximately 1,200 plaintiffs, including wrongful death claims. To date, settlements have been reached with substantially all the plaintiffs associated with the 2022 McKinney Fire, including all wrongful death claims. While only a portion of the associated complaints have been dismissed as a result of the settlements, the remaining settled complaints are also expected to be dismissed. No trials are scheduled for the remaining 2022 McKinney Fire plaintiffs.

On July 25, 2025, a complaint against PacifiCorp was filed, captioned California Department of Transportation v. PacifiCorp, ("Caltrans") in Siskiyou Superior Court California alleging negligence and seeking damages of less than $1 million. The Caltrans complaint was settled in March 2026, and was subsequently dismissed.

Item 1A.Risk Factors

There has been no material change to each Registrant's risk factors from those disclosed in Item 1A of each Registrant's Annual Report on Form 10-K for the year ended December 31, 2025.

Item 2.Unregistered Sales of Equity Securities and Use of Proceeds

Not applicable.

Item 3.Defaults Upon Senior Securities

Not applicable.

202

---

Item 4.Mine Safety Disclosures

Information regarding Berkshire Hathaway Energy's and PacifiCorp's mine safety violations and other legal matters disclosed in accordance with Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act is included in Exhibit 95 to this Form 10-Q.

Item 5.Other Information

Not applicable.

Item 6.Exhibits

The following is a list of exhibits filed as part of this Quarterly Report.

203

---

Exhibit No.			Description

BERKSHIRE HATHAWAY ENERGY

15.1			Awareness Letter of Independent Registered Public Accounting Firm.
31.1			Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2			Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1			Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2			Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

PACIFICORP

15.2			Awareness Letter of Independent Registered Public Accounting Firm.
31.3			Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.4			Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.3			Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.4			Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

BERKSHIRE HATHAWAY ENERGY AND PACIFICORP

4.1			Thirty-Seventh Supplemental Indenture, dated as of March 1, 2026, to the Mortgage and Deed of Trust dated as of January 9, 1989 between PacifiCorp and the Bank of New York Mellon Trust Company, N.A., as successor Trustee (incorporated by reference to Exhibit 4.1 to the PacifiCorp Current Report on Form 8-K dated March 25, 2026).
10.1			Letter of Credit Agreement, dated April 3, 2026, by and among PacifiCorp, PNC Bank, National Association, as administrative agent, the issuing banks party thereto from time to time, and PNC Capital Markets LLC, as lead arranger (incorporated by reference to Exhibit 10.1 to the PacifiCorp Current Report on Form 8-K dated April 6, 2026).
95			Mine Safety Disclosures Required by the Dodd-Frank Wall Street Reform and Consumer Protection Act.

MIDAMERICAN ENERGY

15.3			Awareness Letter of Independent Registered Public Accounting Firm.
31.5			Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.6			Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.5			Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.6			Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

MIDAMERICAN FUNDING

31.7			Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.8			Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.7			Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.8			Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

204

---

Exhibit No.			Description

NEVADA POWER

15.4			Awareness Letter of Independent Registered Public Accounting Firm.
31.9			Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.10			Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.9			Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.10			Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

SIERRA PACIFIC

15.5			Awareness Letter of Independent Registered Public Accounting Firm.
31.11			Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.12			Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.11			Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.12			Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

BERKSHIRE HATHAWAY ENERGY AND SIERRA PACIFIC

4.2			Second Supplemental Indenture, dated as of March 9, 2026, by and between Sierra Pacific Power Company and The Bank of New York Mellon Trust Company, N.A., as trustee, relating to the 6.375% Fixed-to-Fixed Reset Rate Junior Subordinated Notes, SPPC JSN Series 2026A, due 2056 (incorporated by reference to Exhibit 4.2 to the Sierra Pacific Power Company Current Report on Form 8-K dated March 11, 2026).

EASTERN ENERGY GAS

15.6			Awareness Letter of Independent Registered Public Accounting Firm.
31.13			Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.14			Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.13			Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.14			Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

EASTERN GAS TRANSMISSION AND STORAGE

31.15			Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.16			Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.15			Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.16			Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

205

---

Exhibit No.			Description

ALL REGISTRANTS

101			The following financial information from each respective Registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2026, is formatted in iXBRL (Inline eXtensible Business Reporting Language) and included herein: (i) the Consolidated Balance Sheets, (ii) the Consolidated Statements of Operations, (iii) the Consolidated Statements of Comprehensive Income, (iv) the Consolidated Statements of Changes in Equity, (v) the Consolidated Statements of Cash Flows, and (vi) the Notes to Consolidated Financial Statements, tagged in summary and detail.
104			Cover Page Interactive Data File formatted in iXBRL (Inline eXtensible Business Reporting Language) and contained in Exhibit 101.

206

---

SIGNATURES

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

			BERKSHIRE HATHAWAY ENERGY COMPANY
Date: May 1, 2026			/s/ Terrell K. Crews II
			Terrell K. Crews II
			Senior Vice President and Chief Financial Officer
			(principal financial and accounting officer)
			PACIFICORP
Date: May 1, 2026			/s/ M. Ryan Weems
			M. Ryan Weems
			Senior Vice President, Chief Financial Officer and Treasurer
			(principal financial and accounting officer)
			MIDAMERICAN FUNDING, LLC
			MIDAMERICAN ENERGY COMPANY
Date: May 1, 2026			/s/ Blake M. Groen
			Blake M. Groen
			Vice President and Controller
			of MidAmerican Funding, LLC and
			Vice President and Chief Financial Officer
			of MidAmerican Energy Company
			(principal financial and accounting officer)
			NEVADA POWER COMPANY
Date: May 1, 2026			/s/ Michael J. Behrens
			Michael J. Behrens
			Vice President and Chief Financial Officer
			(principal financial and accounting officer)
			SIERRA PACIFIC POWER COMPANY
Date: May 1, 2026			/s/ Michael J. Behrens
			Michael J. Behrens
			Vice President and Chief Financial Officer
			(principal financial and accounting officer)
			EASTERN ENERGY GAS HOLDINGS, LLC
Date: May 1, 2026			/s/ Scott C. Miller
			Scott C. Miller
			Vice President, Chief Financial Officer and Treasurer
			(principal financial and accounting officer)
			EASTERN GAS TRANSMISSION AND STORAGE, INC.
Date: May 1, 2026			/s/ Scott C. Miller
			Scott C. Miller
			Vice President, Chief Financial Officer and Treasurer
			(principal financial and accounting officer)

207

---

ATTACHMENTS / EXHIBITS

BHE AWARENESS LETTER OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

PAC AWARENESS LETTER OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

MEC AWARENESS LETTER OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

NPC AWARENESS LETTER OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

SPPC AWARENESS LETTER OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

EEGH AWARENESS LETTER OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

BHE SECTION 302 CEO CERTIFICATION

BHE SECTION 302 CFO CERTIFICATION

PAC SECTION 302 CEO CERTIFICATION

PAC SECTION 302 CFO CERTIFICATION

MEC SECTION 302 CEO CERTIFICATION

MEC SECTION 302 CFO CERTIFICATION

LLC SECTION 302 CEO CERTIFICATION

LLC SECTION 302 CFO CERTIFICATION

NPC SECTION 302 CEO CERTIFICATION

NPC SECTION 302 CFO CERTIFICATION

SPPC SECTION 302 CEO CERTIFICATION

SPPC SECTION 302 CFO CERTIFICATION

EEGH SECTION 302 CEO CERTIFICATION

EEGH SECTION 302 CFO CERTIFICATION

EGTS SECTION 302 CEO CERTIFICATION

EGTS SECTION 302 CFO CERTIFICATION

BHE SECTION 906 CEO CERTIFICATION

BHE SECTION 906 CFO CERTIFICATION

PAC SECTION 906 CEO CERTIFICATION

PAC SECTION 906 CFO CERTIFICATION

MEC SECTION 906 CEO CERTIFICATION

MEC SECTION 906 CFO CERTIFICATION

LLC SECTION 906 CEO CERTIFICATION

LLC SECTION 906 CFO CERTIFICATION

NPC SECTION 906 CEO CERTIFICATION

NPC SECTION 906 CFO CERTIFICATION

SPPC SECTION 906 CEO CERTIFICATION

SPPC SECTION 906 CFO CERTIFICATION

EEGH SECTION 906 CEO CERTIFICATION

EEGH SECTION 906 CFO CERTIFICATION

EGTS SECTION 906 CEO CERTIFICATION

EGTS SECTION 906 CFO CERTIFICATION

MINE SAFETY DISCLOSURES

XBRL TAXONOMY EXTENSION SCHEMA DOCUMENT

XBRL TAXONOMY EXTENSION CALCULATION LINKBASE DOCUMENT

XBRL TAXONOMY EXTENSION DEFINITION LINKBASE DOCUMENT

XBRL TAXONOMY EXTENSION LABEL LINKBASE DOCUMENT

XBRL TAXONOMY EXTENSION PRESENTATION LINKBASE DOCUMENT

IDEA: R1.htm

IDEA: R2.htm

IDEA: R3.htm

IDEA: R4.htm

IDEA: R5.htm

IDEA: R6.htm

IDEA: R7.htm

IDEA: R8.htm

IDEA: R9.htm

IDEA: R10.htm

IDEA: R11.htm

IDEA: R12.htm

IDEA: R13.htm

IDEA: R14.htm

IDEA: R15.htm

IDEA: R16.htm

IDEA: R17.htm

IDEA: R18.htm

IDEA: R19.htm

IDEA: R20.htm

IDEA: R21.htm

IDEA: R22.htm

IDEA: R23.htm

IDEA: R24.htm

IDEA: R25.htm

IDEA: R26.htm

IDEA: R27.htm

IDEA: R28.htm

IDEA: R29.htm

IDEA: R30.htm

IDEA: R31.htm

IDEA: R32.htm

IDEA: R33.htm

IDEA: R34.htm

IDEA: R35.htm

IDEA: R36.htm

IDEA: R37.htm

IDEA: R38.htm

IDEA: R39.htm

IDEA: R40.htm

IDEA: R41.htm

IDEA: R42.htm

IDEA: R43.htm

IDEA: R44.htm

IDEA: R45.htm

IDEA: R46.htm

IDEA: R47.htm

IDEA: R48.htm

IDEA: R49.htm

IDEA: R50.htm

IDEA: R51.htm

IDEA: R52.htm

IDEA: R53.htm

IDEA: R54.htm

IDEA: R55.htm

IDEA: R56.htm

IDEA: R57.htm

IDEA: R58.htm

IDEA: R59.htm

IDEA: R60.htm

IDEA: R61.htm

IDEA: R62.htm

IDEA: R63.htm

IDEA: R64.htm

IDEA: R65.htm

IDEA: R66.htm

IDEA: R67.htm

IDEA: R68.htm

IDEA: R69.htm

IDEA: R70.htm

IDEA: R71.htm

IDEA: R72.htm

IDEA: R73.htm

IDEA: R74.htm

IDEA: R75.htm

IDEA: R76.htm

IDEA: R77.htm

IDEA: R78.htm

IDEA: R79.htm

IDEA: R80.htm

IDEA: R81.htm

IDEA: R82.htm

IDEA: R83.htm

IDEA: R84.htm

IDEA: R85.htm

IDEA: R86.htm

IDEA: R87.htm

IDEA: R88.htm

IDEA: R89.htm

IDEA: R90.htm

IDEA: R91.htm

IDEA: R92.htm

IDEA: R93.htm

IDEA: R94.htm

IDEA: R95.htm

IDEA: R96.htm

IDEA: R97.htm

IDEA: R98.htm

IDEA: R99.htm

IDEA: R100.htm

IDEA: R101.htm

IDEA: R102.htm

IDEA: R103.htm

IDEA: R104.htm

IDEA: R105.htm

IDEA: R106.htm

IDEA: R107.htm

IDEA: R108.htm

IDEA: R109.htm

IDEA: R110.htm

IDEA: R111.htm

IDEA: R112.htm

IDEA: R113.htm

IDEA: R114.htm

IDEA: R115.htm

IDEA: R116.htm

IDEA: R117.htm

IDEA: R118.htm

IDEA: R119.htm

IDEA: R120.htm

IDEA: R121.htm

IDEA: R122.htm

IDEA: R123.htm

IDEA: R124.htm

IDEA: R125.htm

IDEA: R126.htm

IDEA: R127.htm

IDEA: R128.htm

IDEA: R129.htm

IDEA: R130.htm

IDEA: R131.htm

IDEA: R132.htm

IDEA: R133.htm

IDEA: R134.htm

IDEA: R135.htm

IDEA: R136.htm

IDEA: R137.htm

IDEA: R138.htm

IDEA: R139.htm

IDEA: R140.htm

IDEA: R141.htm

IDEA: R142.htm

IDEA: R143.htm

IDEA: R144.htm

IDEA: R145.htm

IDEA: R146.htm

IDEA: R147.htm

IDEA: R148.htm

IDEA: R149.htm

IDEA: R150.htm

IDEA: R151.htm

IDEA: R152.htm

IDEA: R153.htm

IDEA: R154.htm

IDEA: R155.htm

IDEA: R156.htm

IDEA: R157.htm

IDEA: R158.htm

IDEA: R159.htm

IDEA: R160.htm

IDEA: R161.htm

IDEA: R162.htm

IDEA: R163.htm

IDEA: R164.htm

IDEA: R165.htm

IDEA: R166.htm

IDEA: R167.htm

IDEA: R168.htm

IDEA: R169.htm

IDEA: R170.htm

IDEA: R171.htm

IDEA: R172.htm

IDEA: R173.htm

IDEA: R174.htm

IDEA: R175.htm

IDEA: R176.htm

IDEA: R177.htm

IDEA: R178.htm

IDEA: R179.htm

IDEA: R180.htm

IDEA: R181.htm

IDEA: R182.htm

IDEA: R183.htm

IDEA: R184.htm

IDEA: R185.htm

IDEA: R186.htm

IDEA: R187.htm

IDEA: R188.htm

IDEA: FilingSummary.xml

IDEA: MetaLinks.json

IDEA: bhe-20260331_htm.xml