Companies: 10,646     total market cap: C$193.813 T
$USD๐Ÿ‡บ๐Ÿ‡ธโ‚ฌEUR๐Ÿ‡ช๐Ÿ‡บโ‚นINR๐Ÿ‡ฎ๐Ÿ‡ณยฃGBP๐Ÿ‡ฌ๐Ÿ‡ง$AUD๐Ÿ‡ฆ๐Ÿ‡บ$NZD๐Ÿ‡ณ๐Ÿ‡ฟ$HKD๐Ÿ‡ญ๐Ÿ‡ฐ$SGD๐Ÿ‡ธ๐Ÿ‡ฌ
Edison International
EIX
#880
Rank
C$38.81 B
Marketcap
๐Ÿ‡บ๐Ÿ‡ธ United States
Country
C$100.86
Share price
1.49%
Change (1 day)
41.42%
Change (1 year)
๐Ÿ”‹ Electricity๐Ÿšฐ Utility companies โšก Energy
Categories
  1. Edison International
  2. Annual Reports (10-K)
  3. Submitted on 2026-02-18

Edison International - 10-K annual report


Text size:
0000827052FYFALSE20250000092103FYFALSE2025http://fasb.org/us-gaap/2025#AssetImpairmentChargeshttp://xbrl.sec.gov/country/2025#UShttp://xbrl.sec.gov/country/2025#UShttp://xbrl.sec.gov/country/2025#USP3Yhttp://fasb.org/us-gaap/2025#OtherLiabilitiesNoncurrent791iso4217:USDxbrli:sharesiso4217:USDxbrli:sharesutr:sqmixbrli:pureutr:MWiso4217:USDutr:MWhutr:GWhutr:Bcfeutr:acreeix:itemeix:individualeix:plaintiffeix:structureeix:injuryeix:conductoreix:lawsuiteix:site00008270522025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-3100008270522025-06-3000008270522026-02-110000827052eix:SouthernCaliforniaEdisonCompanyMember2026-02-110000827052eix:SeriesKPreferredStockMembereix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SubsequentEventMember2026-02-1000008270522024-01-012024-12-3100008270522023-01-012023-12-3100008270522025-12-3100008270522024-12-310000827052eix:SCERecoveryFundingLLCMember2025-12-310000827052eix:SCERecoveryFundingLLCMember2024-12-310000827052us-gaap:SeriesAPreferredStockMember2025-12-310000827052us-gaap:SeriesAPreferredStockMember2024-12-310000827052us-gaap:SeriesBPreferredStockMember2025-12-310000827052us-gaap:SeriesBPreferredStockMember2024-12-3100008270522023-12-3100008270522022-12-310000827052us-gaap:PreferredStockMember2022-12-310000827052us-gaap:CommonStockMember2022-12-310000827052us-gaap:AccumulatedOtherComprehensiveIncomeMember2022-12-310000827052us-gaap:RetainedEarningsMember2022-12-310000827052us-gaap:ParentMember2022-12-310000827052us-gaap:NoncontrollingInterestMember2022-12-310000827052us-gaap:RetainedEarningsMember2023-01-012023-12-310000827052us-gaap:ParentMember2023-01-012023-12-310000827052us-gaap:NoncontrollingInterestMember2023-01-012023-12-310000827052us-gaap:AccumulatedOtherComprehensiveIncomeMember2023-01-012023-12-310000827052us-gaap:CommonStockMember2023-01-012023-12-310000827052us-gaap:SeriesAPreferredStockMember2023-01-012023-12-310000827052us-gaap:SeriesBPreferredStockMember2023-01-012023-12-310000827052eix:O2022AMinimumDividendsMember2023-01-012023-12-310000827052eix:O2022AMaximumDividendsMember2023-01-012023-12-310000827052us-gaap:CommonStockIncludingAdditionalPaidInCapitalMember2023-01-012023-12-310000827052us-gaap:PreferredStockMember2023-01-012023-12-310000827052us-gaap:PreferredStockMember2023-12-310000827052us-gaap:CommonStockMember2023-12-310000827052us-gaap:AccumulatedOtherComprehensiveIncomeMember2023-12-310000827052us-gaap:RetainedEarningsMember2023-12-310000827052us-gaap:ParentMember2023-12-310000827052us-gaap:NoncontrollingInterestMember2023-12-310000827052us-gaap:RetainedEarningsMember2024-01-012024-12-310000827052us-gaap:ParentMember2024-01-012024-12-310000827052us-gaap:NoncontrollingInterestMember2024-01-012024-12-310000827052us-gaap:AccumulatedOtherComprehensiveIncomeMember2024-01-012024-12-310000827052us-gaap:CommonStockMember2024-01-012024-12-310000827052us-gaap:SeriesAPreferredStockMember2024-01-012024-12-310000827052us-gaap:SeriesBPreferredStockMember2024-01-012024-12-310000827052eix:O2023AMinimumDividendsMember2024-01-012024-12-310000827052eix:O2023AMaximumDividendsMember2024-01-012024-12-310000827052us-gaap:CommonStockIncludingAdditionalPaidInCapitalMember2024-01-012024-12-310000827052us-gaap:PreferredStockMember2024-01-012024-12-310000827052us-gaap:PreferredStockMember2024-12-310000827052us-gaap:CommonStockMember2024-12-310000827052us-gaap:AccumulatedOtherComprehensiveIncomeMember2024-12-310000827052us-gaap:RetainedEarningsMember2024-12-310000827052us-gaap:ParentMember2024-12-310000827052us-gaap:NoncontrollingInterestMember2024-12-310000827052us-gaap:RetainedEarningsMember2025-01-012025-12-310000827052us-gaap:ParentMember2025-01-012025-12-310000827052us-gaap:NoncontrollingInterestMember2025-01-012025-12-310000827052us-gaap:AccumulatedOtherComprehensiveIncomeMember2025-01-012025-12-310000827052us-gaap:CommonStockMember2025-01-012025-12-310000827052us-gaap:SeriesAPreferredStockMember2025-01-012025-12-310000827052us-gaap:SeriesBPreferredStockMember2025-01-012025-12-310000827052eix:O2024AMinimumDividendsMember2025-01-012025-12-310000827052eix:O2024AMaximumDividendsMember2025-01-012025-12-310000827052us-gaap:PreferredStockMember2025-01-012025-12-310000827052us-gaap:CommonStockIncludingAdditionalPaidInCapitalMember2025-01-012025-12-310000827052us-gaap:PreferredStockMember2025-12-310000827052us-gaap:CommonStockMember2025-12-310000827052us-gaap:AccumulatedOtherComprehensiveIncomeMember2025-12-310000827052us-gaap:RetainedEarningsMember2025-12-310000827052us-gaap:ParentMember2025-12-310000827052us-gaap:NoncontrollingInterestMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SCERecoveryFundingLLCMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SCERecoveryFundingLLCMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:NonrelatedPartyMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:NonrelatedPartyMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembersrt:AffiliatedEntityMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembersrt:AffiliatedEntityMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMember2022-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2022-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:CommonStockMember2022-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AdditionalPaidInCapitalMember2022-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2022-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RetainedEarningsMember2022-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RetainedEarningsMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:O2022AMinimumDividendsMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:O2022AMaximumDividendsMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AdditionalPaidInCapitalMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:CommonStockMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AdditionalPaidInCapitalMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RetainedEarningsMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RetainedEarningsMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AdditionalPaidInCapitalMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:O2023AMinimumDividendsMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:O2023AMaximumDividendsMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:CommonStockMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AdditionalPaidInCapitalMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RetainedEarningsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RetainedEarningsMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:O2024AMinimumDividendsMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:O2024AMaximumDividendsMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AdditionalPaidInCapitalMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:CommonStockMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AdditionalPaidInCapitalMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AccumulatedOtherComprehensiveIncomeMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RetainedEarningsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SalesChannelDirectlyToConsumerMember2022-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SalesChannelAllOthersMember2022-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SalesChannelDirectlyToConsumerMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SalesChannelAllOthersMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SalesChannelDirectlyToConsumerMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SalesChannelAllOthersMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SalesChannelDirectlyToConsumerMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SalesChannelAllOthersMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SalesChannelDirectlyToConsumerMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SalesChannelAllOthersMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SalesChannelDirectlyToConsumerMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SalesChannelAllOthersMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SalesChannelDirectlyToConsumerMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SalesChannelAllOthersMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:LCFSNetSalesProceedsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:LCFSNetSalesProceedsMember2024-12-310000827052eix:GenerationPlantMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:GenerationPlantMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:GenerationPlantMembersrt:WeightedAverageMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:ElectricDistributionMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:ElectricDistributionMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:ElectricDistributionMembersrt:WeightedAverageMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:ElectricTransmissionMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:ElectricTransmissionMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:ElectricTransmissionMembersrt:WeightedAverageMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:GeneralPlantAndOtherMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:GeneralPlantAndOtherMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:GeneralPlantAndOtherMembersrt:WeightedAverageMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:InterestExpenseMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052us-gaap:InterestExpenseMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052us-gaap:InterestExpenseMembereix:SouthernCaliforniaEdisonCompanyMember2023-01-012023-12-310000827052us-gaap:OtherIncomeMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052us-gaap:OtherIncomeMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052us-gaap:OtherIncomeMembereix:SouthernCaliforniaEdisonCompanyMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMember2025-09-012025-09-300000827052eix:TKMSettlementAgreementMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:WoolseySettlementAgreementMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:WildfireInsuranceFundMember2025-12-310000827052eix:WildfireInsuranceFundMember2024-12-310000827052eix:WildfireInsuranceFundMember2020-01-012020-12-310000827052eix:WildfireInsuranceFundMember2025-01-012025-12-310000827052eix:WildfireInsuranceFundMember2024-01-012024-12-310000827052eix:WildfireInsuranceFundMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:EatonFireMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PaloVerdeAndSanOnofreUnitsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PaloVerdeAndSanOnofreUnitsMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMember2025-09-300000827052us-gaap:EmployeeStockMember2021-07-310000827052srt:MinimumMemberus-gaap:EmployeeStockMember2021-07-310000827052srt:MaximumMemberus-gaap:EmployeeStockMember2021-07-310000827052us-gaap:EmployeeStockMember2021-07-012021-07-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SubsequentEventMember2026-02-182026-02-1800008270522025-12-012025-12-3100008270522025-12-010000827052us-gaap:SubsequentEventMember2026-02-182026-02-180000827052srt:MinimumMemberus-gaap:SubsequentEventMember2026-02-180000827052srt:MaximumMemberus-gaap:SubsequentEventMember2026-02-180000827052eix:ConstructionWorkInProgressMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:ConstructionWorkInProgressMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052srt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SoftwareAndSoftwareDevelopmentCostsMember2025-12-310000827052srt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SoftwareAndSoftwareDevelopmentCostsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:EldoradoMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PacificIntertieMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PaloVerdeNuclearMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SCEPowerPurchasesContractsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SCEPowerPurchasesContractsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PowerPurchaseAgreementMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PowerPurchaseAgreementMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:FairValueInputsLevel1Member2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:FairValueInputsLevel2Member2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:FairValueInputsLevel3Member2025-12-310000827052us-gaap:EquitySecuritiesMemberus-gaap:FairValueInputsLevel1Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:EquitySecuritiesMemberus-gaap:FairValueInputsLevel2Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:EquitySecuritiesMemberus-gaap:FairValueInputsLevel3Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:EquitySecuritiesMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:FixedIncomeSecuritiesMemberus-gaap:FairValueInputsLevel1Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:FixedIncomeSecuritiesMemberus-gaap:FairValueInputsLevel2Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:FixedIncomeSecuritiesMemberus-gaap:FairValueInputsLevel3Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:FixedIncomeSecuritiesMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:ShortTermInvestmentsPrimarilyCashEquivalentsMemberus-gaap:FairValueInputsLevel1Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:ShortTermInvestmentsPrimarilyCashEquivalentsMemberus-gaap:FairValueInputsLevel2Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:ShortTermInvestmentsPrimarilyCashEquivalentsMemberus-gaap:FairValueInputsLevel3Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:ShortTermInvestmentsPrimarilyCashEquivalentsMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:FairValueInputsLevel1Member2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:FairValueInputsLevel2Member2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:FairValueInputsLevel3Member2024-12-310000827052us-gaap:EquitySecuritiesMemberus-gaap:FairValueInputsLevel1Membereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:EquitySecuritiesMemberus-gaap:FairValueInputsLevel2Membereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:EquitySecuritiesMemberus-gaap:FairValueInputsLevel3Membereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:EquitySecuritiesMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:FixedIncomeSecuritiesMemberus-gaap:FairValueInputsLevel1Membereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:FixedIncomeSecuritiesMemberus-gaap:FairValueInputsLevel2Membereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:FixedIncomeSecuritiesMemberus-gaap:FairValueInputsLevel3Membereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:FixedIncomeSecuritiesMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:ShortTermInvestmentsPrimarilyCashEquivalentsMemberus-gaap:FairValueInputsLevel1Membereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:ShortTermInvestmentsPrimarilyCashEquivalentsMemberus-gaap:FairValueInputsLevel2Membereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:ShortTermInvestmentsPrimarilyCashEquivalentsMemberus-gaap:FairValueInputsLevel3Membereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:ShortTermInvestmentsPrimarilyCashEquivalentsMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:FairValueInputsLevel3Member2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:FairValueInputsLevel3Member2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:FairValueInputsLevel3Member2024-01-012024-12-310000827052eix:CongestionRevenueRightsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:CongestionRevenueRightsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:CongestionRevenueRightsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:CongestionRevenueRightsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembersrt:WeightedAverageMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:FinTollArrangementsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:FinTollArrangementsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:FinTollArrangementsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:FinTollArrangementsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembersrt:WeightedAverageMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:CongestionRevenueRightsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:CongestionRevenueRightsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:CongestionRevenueRightsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:CongestionRevenueRightsGWhMemberus-gaap:FairValueInputsLevel3Memberus-gaap:MarketApproachValuationTechniqueMembersrt:WeightedAverageMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:EdisonInternationalParentAndOtherMemberus-gaap:FairValueInputsLevel1Member2025-12-310000827052eix:EdisonInternationalParentAndOtherMemberus-gaap:FairValueInputsLevel1Member2024-12-310000827052eix:EdisonInternationalParentAndOtherMemberus-gaap:FairValueInputsLevel3Member2024-12-310000827052eix:EdisonInternationalParentAndOtherMemberus-gaap:FairValueInputsLevel3Member2025-12-310000827052eix:DebenturesAndNotesMembersrt:MinimumMembereix:EdisonInternationalParentAndOtherMember2025-12-310000827052eix:DebenturesAndNotesMembersrt:MaximumMembereix:EdisonInternationalParentAndOtherMember2025-12-310000827052eix:DebenturesAndNotesMembereix:EdisonInternationalParentAndOtherMember2025-12-310000827052eix:DebenturesAndNotesMembereix:EdisonInternationalParentAndOtherMember2024-12-310000827052eix:EdisonInternationalParentAndOtherMember2025-12-310000827052eix:EdisonInternationalParentAndOtherMember2024-12-310000827052eix:FirstAndRefundingMortgageBondsMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:FirstAndRefundingMortgageBondsMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:FirstAndRefundingMortgageBondsMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:FirstAndRefundingMortgageBondsMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:PollutionControlBondsMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:PollutionControlBondsMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:PollutionControlBondsMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:PollutionControlBondsMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:DebenturesAndNotesMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:DebenturesAndNotesMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:DebenturesAndNotesMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:DebenturesAndNotesMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:SeniorSecuredRecoveryBondsMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:SeniorSecuredRecoveryBondsMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:SeniorSecuredRecoveryBondsMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:SeniorSecuredRecoveryBondsMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:OtherLongTermDebtMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:OtherLongTermDebtMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:SeniorSecuredRecoveryBonds4.45PercentDue2038Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:SeniorSecuredRecoveryBonds5.34PercentDue2047Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:SeniorSecuredRecoveryBonds5.54PercentDue2052Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:MultiYearCreditFacilitiesMembereix:EdisonInternationalParentAndOtherMember2025-01-012025-12-310000827052eix:MultiYearCreditFacilitiesMembereix:EdisonInternationalParentAndOtherMember2025-12-310000827052eix:MultiYearCreditFacilitiesMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:MultiYearCreditFacilitiesMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:CommercialPaperMembereix:MultiYearCreditFacilitiesMembereix:EdisonInternationalParentAndOtherMember2025-12-310000827052us-gaap:CommercialPaperMembereix:MultiYearCreditFacilitiesMembereix:EdisonInternationalParentAndOtherMember2024-12-310000827052us-gaap:CommercialPaperMembereix:MultiYearCreditFacilitiesMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:CommercialPaperMembereix:MultiYearCreditFacilitiesMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:MultiYearCreditFacilitiesMembereix:EdisonInternationalParentAndOtherMember2024-05-310000827052eix:MultiYearCreditFacilitiesMembereix:SouthernCaliforniaEdisonCompanyMember2024-05-310000827052us-gaap:UnsecuredDebtMembereix:TermLoanAgreementDueDecember2026Membereix:EdisonInternationalParentAndOtherMember2025-01-012025-12-310000827052us-gaap:UnsecuredDebtMemberus-gaap:SecuredOvernightFinancingRateSofrMembereix:TermLoanAgreementDueDecember2026Membereix:EdisonInternationalParentAndOtherMember2025-12-310000827052us-gaap:UnsecuredDebtMemberus-gaap:BaseRateMembereix:TermLoanAgreementDueDecember2026Membereix:EdisonInternationalParentAndOtherMember2025-12-310000827052us-gaap:StandbyLettersOfCreditMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:TermLoanAgreementDueMarch2027Membereix:EdisonInternationalParentAndOtherMemberus-gaap:SecuredDebtMemberus-gaap:SubsequentEventMember2026-02-012026-02-280000827052us-gaap:SecuredOvernightFinancingRateSofrMembereix:TermLoanAgreementDueMarch2027Membereix:EdisonInternationalParentAndOtherMemberus-gaap:SubsequentEventMember2026-02-280000827052us-gaap:CommodityContractMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:CommodityContractMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:CommodityContractMemberus-gaap:OtherCurrentLiabilitiesMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:CommodityContractMemberus-gaap:OtherCurrentAssetsMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:ElectricityOptionsSwapsAndForwardsGWhMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:ElectricityOptionsSwapsAndForwardsGWhMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:NaturalGasOptionsSwapsAndForwardsBcfMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:NaturalGasOptionsSwapsAndForwardsBcfMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:CongestionRevenueRightsGWhMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:CongestionRevenueRightsGWhMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:FinTollArrangementsGWhMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:FinTollArrangementsGWhMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:CommercialMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:CommercialMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:CommercialMembereix:SouthernCaliforniaEdisonCompanyMember2023-01-012023-12-310000827052eix:ResidentialMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:ResidentialMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:ResidentialMembereix:SouthernCaliforniaEdisonCompanyMember2023-01-012023-12-310000827052eix:OtherOperatingRevenueMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:OtherOperatingRevenueMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:OtherOperatingRevenueMembereix:SouthernCaliforniaEdisonCompanyMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:WestOfDeversMember2025-12-310000827052us-gaap:ValuationAllowanceOperatingLossCarryforwardsMember2025-12-310000827052us-gaap:ValuationAllowanceOperatingLossCarryforwardsMember2024-12-310000827052eix:ExpireBetween2027To2030Member2025-12-310000827052eix:ExpireBetween2027To2030Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:ExpireBetween2031To2045Member2025-12-310000827052eix:ExpireBetween2031To2045Membereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:NoExpirationDateMember2025-12-310000827052eix:NoExpirationDateMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:CapistranoWindMember2025-01-012025-12-310000827052eix:CapistranoWindMember2024-01-012024-12-310000827052us-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:PensionPlansDefinedBenefitMember2025-01-012025-12-310000827052us-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:PensionPlansDefinedBenefitMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PensionPlansDefinedBenefitMember2023-12-310000827052us-gaap:PensionPlansDefinedBenefitMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PensionPlansDefinedBenefitMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PensionPlansDefinedBenefitMember2024-01-012024-12-310000827052srt:ParentCompanyMemberus-gaap:PensionPlansDefinedBenefitMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052srt:ParentCompanyMemberus-gaap:PensionPlansDefinedBenefitMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:PensionPlansDefinedBenefitMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PensionPlansDefinedBenefitMember2023-01-012023-12-310000827052us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-01-012025-12-310000827052us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2023-12-310000827052us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2023-01-012023-12-310000827052us-gaap:FixedIncomeSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052eix:GlobalEquitiesMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052eix:OpportunisticAlternativeInvestmentsMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FixedIncomeSecuritiesMemberus-gaap:OtherPensionPlansPostretirementOrSupplementalPlansDefinedBenefitMember2025-12-310000827052eix:GlobalEquitiesMemberus-gaap:OtherPensionPlansPostretirementOrSupplementalPlansDefinedBenefitMember2025-12-310000827052eix:OpportunisticAlternativeInvestmentsMemberus-gaap:OtherPensionPlansPostretirementOrSupplementalPlansDefinedBenefitMember2025-12-310000827052us-gaap:FixedIncomeSecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052eix:GlobalEquitiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052eix:OpportunisticAlternativeInvestmentsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2025-12-310000827052us-gaap:USTreasuryAndGovernmentMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2025-12-310000827052us-gaap:DefinedBenefitPlanEquitySecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:CorporateBondSecuritiesMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:CorporateBondSecuritiesMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:CorporateBondSecuritiesMember2025-12-310000827052us-gaap:CorporateBondSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2025-12-310000827052eix:CommonCollectiveFundsMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2025-12-310000827052eix:PartnershipsJointVenturesMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentCompaniesMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentCompaniesMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentCompaniesMember2025-12-310000827052us-gaap:OtherInvestmentCompaniesMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2025-12-310000827052us-gaap:HedgeFundsGlobalOpportunityMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2025-12-310000827052us-gaap:InterestBearingDepositsMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2025-12-310000827052us-gaap:OtherInvestmentsMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2024-12-310000827052us-gaap:USTreasuryAndGovernmentMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2024-12-310000827052us-gaap:DefinedBenefitPlanEquitySecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:CorporateBondSecuritiesMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:CorporateBondSecuritiesMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:CorporateBondSecuritiesMember2024-12-310000827052us-gaap:CorporateBondSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052eix:CommonCollectiveFundsMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2024-12-310000827052eix:PartnershipsJointVenturesMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentCompaniesMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentCompaniesMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentCompaniesMember2024-12-310000827052us-gaap:OtherInvestmentCompaniesMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2024-12-310000827052us-gaap:HedgeFundsGlobalOpportunityMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2024-12-310000827052us-gaap:InterestBearingDepositsMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2024-12-310000827052us-gaap:OtherInvestmentsMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052eix:RussellIndexesMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2024-12-310000827052eix:MSCIMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2024-12-310000827052eix:CollateralizedMortgageObligationsAndOtherAssetBackedSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052eix:CollateralizedMortgageObligationsAndOtherAssetBackedSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052eix:MSCIAllCountryWorldIndexExUSMemberus-gaap:PensionPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2025-12-310000827052eix:NonIndexU.S.EquityFundMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052eix:StandardAndPoors500Memberus-gaap:PensionPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052eix:MSCIAllCountryWorldIndexExUSMemberus-gaap:PensionPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052eix:NonIndexU.S.EquityFundMemberus-gaap:PensionPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052eix:PrivateEquityAndVentureCapitalFundsIncludingBrandedConsumerProductsCleanAndInformationTechnologyAndHealthcareMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052eix:PrivateEquityAndVentureCapitalFundsIncludingBrandedConsumerProductsCleanAndInformationTechnologyAndHealthcareMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052eix:BroadRangeOfFinancialAssetsInAllGlobalMarketsMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052eix:BroadRangeOfFinancialAssetsInAllGlobalMarketsMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052eix:AssetBackedSecuritiesIncludingDistressedMortgagesMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FixedIncomeSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052eix:DomesticMortgageBackedSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052eix:DomesticMortgageBackedSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052eix:HighYieldDebtSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052eix:HighYieldDebtSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FixedIncomeFundsMemberus-gaap:PensionPlansDefinedBenefitMember2025-12-310000827052us-gaap:FixedIncomeFundsMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:EquityFundsMemberus-gaap:PensionPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2025-12-310000827052us-gaap:USTreasuryAndGovernmentMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2025-12-310000827052us-gaap:DefinedBenefitPlanEquitySecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CorporateNotesAndBondsMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CorporateNotesAndBondsMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CorporateNotesAndBondsMember2025-12-310000827052eix:CorporateNotesAndBondsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2025-12-310000827052eix:CommonCollectiveFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2025-12-310000827052eix:PartnershipsJointVenturesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2025-12-310000827052us-gaap:HedgeFundsGlobalOpportunityMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2025-12-310000827052us-gaap:InterestBearingDepositsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2025-12-310000827052us-gaap:OtherInvestmentsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:USTreasuryAndGovernmentMember2024-12-310000827052us-gaap:USTreasuryAndGovernmentMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2024-12-310000827052us-gaap:DefinedBenefitPlanEquitySecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CorporateNotesAndBondsMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CorporateNotesAndBondsMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CorporateNotesAndBondsMember2024-12-310000827052eix:CorporateNotesAndBondsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052eix:CommonCollectiveFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:PartnershipsJointVenturesMember2024-12-310000827052eix:PartnershipsJointVenturesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:HedgeFundsGlobalOpportunityMember2024-12-310000827052us-gaap:HedgeFundsGlobalOpportunityMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:InterestBearingDepositsMember2024-12-310000827052us-gaap:InterestBearingDepositsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:OtherInvestmentsMember2024-12-310000827052us-gaap:OtherInvestmentsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel1Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueInputsLevel2Memberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:FairValueMeasuredAtNetAssetValuePerShareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052eix:RussellIndexesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2025-12-310000827052eix:RussellIndexesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2024-12-310000827052eix:MSCIAllCountryWorldIndexMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2025-12-310000827052eix:MSCIAllCountryWorldIndexMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:DefinedBenefitPlanEquitySecuritiesMember2024-12-310000827052eix:CollateralizedMortgageObligationsAndOtherAssetBackedSecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052eix:CollateralizedMortgageObligationsAndOtherAssetBackedSecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052eix:MSCIAllCountryWorldIndexInvestableMarketIndexMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2025-12-310000827052eix:MSCIAllCountryWorldIndexInvestableMarketIndexMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052eix:NonIndexU.S.EquityFundMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMembereix:CommonCollectiveFundsMember2024-12-310000827052eix:PrivateEquityAndVentureCapitalFundsIncludingBrandedConsumerProductsCleanAndInformationTechnologyAndHealthcareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052eix:PrivateEquityAndVentureCapitalFundsIncludingBrandedConsumerProductsCleanAndInformationTechnologyAndHealthcareMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052eix:AssetBackedSecuritiesIncludingDistressedMortgagesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052eix:AssetBackedSecuritiesIncludingDistressedMortgagesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052eix:BroadRangeOfFinancialAssetsInAllGlobalMarketsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052eix:BroadRangeOfFinancialAssetsInAllGlobalMarketsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:MoneyMarketFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:MoneyMarketFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:DefinedBenefitPlanEquitySecuritiesSmallCapMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:DefinedBenefitPlanEquitySecuritiesSmallCapMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:MunicipalNotesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2025-12-310000827052us-gaap:MunicipalNotesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2024-12-310000827052us-gaap:EmployeeStockOptionMember2025-01-012025-12-310000827052us-gaap:EmployeeStockOptionMember2024-01-012024-12-310000827052us-gaap:EmployeeStockOptionMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:EmployeeStockOptionMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:EmployeeStockOptionMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:EmployeeStockOptionMember2023-01-012023-12-310000827052us-gaap:PerformanceSharesMember2025-01-012025-12-310000827052us-gaap:PerformanceSharesMember2024-01-012024-12-310000827052us-gaap:PerformanceSharesMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PerformanceSharesMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PerformanceSharesMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PerformanceSharesMember2023-01-012023-12-310000827052us-gaap:RestrictedStockUnitsRSUMember2025-01-012025-12-310000827052us-gaap:RestrictedStockUnitsRSUMember2024-01-012024-12-310000827052us-gaap:RestrictedStockUnitsRSUMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RestrictedStockUnitsRSUMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RestrictedStockUnitsRSUMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RestrictedStockUnitsRSUMember2023-01-012023-12-310000827052eix:OtherStockAwardsMember2025-01-012025-12-310000827052eix:OtherStockAwardsMember2024-01-012024-12-310000827052eix:OtherStockAwardsMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherStockAwardsMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherStockAwardsMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherStockAwardsMember2023-01-012023-12-310000827052srt:MinimumMemberus-gaap:EmployeeStockOptionMember2025-01-012025-12-310000827052srt:MaximumMemberus-gaap:EmployeeStockOptionMember2025-01-012025-12-310000827052srt:MinimumMemberus-gaap:EmployeeStockOptionMember2024-01-012024-12-310000827052srt:MaximumMemberus-gaap:EmployeeStockOptionMember2024-01-012024-12-310000827052srt:MinimumMemberus-gaap:EmployeeStockOptionMember2023-01-012023-12-310000827052srt:MaximumMemberus-gaap:EmployeeStockOptionMember2023-01-012023-12-310000827052srt:WeightedAverageMemberus-gaap:EmployeeStockOptionMember2025-01-012025-12-310000827052srt:WeightedAverageMemberus-gaap:EmployeeStockOptionMember2024-01-012024-12-310000827052srt:WeightedAverageMemberus-gaap:EmployeeStockOptionMember2023-01-012023-12-310000827052us-gaap:EmployeeStockOptionMember2024-12-310000827052us-gaap:EmployeeStockOptionMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:EmployeeStockOptionMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:EmployeeStockOptionMember2025-12-310000827052us-gaap:PerformanceSharesMember2024-12-310000827052us-gaap:PerformanceSharesMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PerformanceSharesMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PerformanceSharesMember2025-12-310000827052us-gaap:RestrictedStockUnitsRSUMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RestrictedStockUnitsRSUMember2024-12-310000827052us-gaap:RestrictedStockUnitsRSUMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RestrictedStockUnitsRSUMember2025-12-310000827052us-gaap:MunicipalBondsMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:MunicipalBondsMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:USTreasuryAndGovernmentMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:USTreasuryAndGovernmentMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:CorporateBondSecuritiesMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:CorporateBondSecuritiesMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:ShortTermInvestmentsNettingMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:ShortTermInvestmentsNettingMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:DebtSecuritiesAndOtherMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:DebtSecuritiesAndOtherMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:EquitySecuritiesMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:EquitySecuritiesMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052us-gaap:RepurchaseAgreementsMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052us-gaap:RepurchaseAgreementsMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:UnamortizedInvestmentsNetOfAccumulatedAmortizationMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:UnamortizedInvestmentsNetOfAccumulatedAmortizationMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RegulatoryClauseRevenuesUnderRecoveredMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RegulatoryClauseRevenuesUnderRecoveredMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:OtherRegulatoryAssetsLiabilitiesMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:OtherRegulatoryAssetsLiabilitiesMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:DeferredIncomeTaxChargesMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:DeferredIncomeTaxChargesMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:LossOnReacquiredDebtMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:LossOnReacquiredDebtMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:EnvironmentalRestorationCostsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:EnvironmentalRestorationCostsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:RecoveryAssetsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:RecoveryAssetsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RevenueSubjectToRefundMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:RevenueSubjectToRefundMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:DeferredDerivativeGainLossMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:DeferredDerivativeGainLossMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:OtherRegulatoryAssetsLiabilitiesMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:OtherRegulatoryAssetsLiabilitiesMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:CostsOfRemovalMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:CostsOfRemovalMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:DeferredIncomeTaxChargesMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:DeferredIncomeTaxChargesMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AssetRetirementObligationCostsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:AssetRetirementObligationCostsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PensionAndOtherPostretirementPlansCostsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PensionAndOtherPostretirementPlansCostsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:EnergyProcurementRelatedCostsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:EnergyProcurementRelatedCostsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PublicPurposeAndEnergyEfficiencyMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PublicPurposeAndEnergyEfficiencyMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:GRCRelatedBalancingAccountsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:GRCRelatedBalancingAccountsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:FERCRelatedBalancingAccountsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:FERCRelatedBalancingAccountsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:WildfireRiskMitigationAndInsuranceMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:WildfireRiskMitigationAndInsuranceMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:WildfireAndDroughtRestorationMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:WildfireAndDroughtRestorationMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:WoolseySettlementCostRecoveryMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:WoolseySettlementCostRecoveryMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:TaxAccountingMemorandumAccountMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:TaxAccountingMemorandumAccountMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:GridHardeningBalancingAccountMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PowerPurchaseAgreementMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PowerPurchaseAgreementMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PowerPurchaseAgreementMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PowerPurchaseAgreementMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherContractualObligationsMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherContractualObligationsMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherContractualObligationsMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:December2017WildfiresMember2017-12-040000827052eix:SouthernCaliforniaEdisonCompanyMembereix:November2018WildfiresMember2018-11-300000827052eix:SouthernCaliforniaEdisonCompanyMembereix:MontecitoMudslidesMember2018-01-310000827052eix:MontecitoMudslidesMembereix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SubsequentEventMember2026-02-112026-02-110000827052eix:A20172018WildfireMudslideEventsMembereix:SEDSettlementMembereix:SouthernCaliforniaEdisonCompanyMember2021-10-310000827052eix:A20172018WildfireMudslideEventsMembereix:SEDSettlementMembereix:SouthernCaliforniaEdisonCompanyMember2021-10-012021-10-310000827052eix:ThomasKoenigsteinFiresAndMontecitoMudslidesMembereix:SEDSettlementMembereix:SouthernCaliforniaEdisonCompanyMember2021-10-012021-10-310000827052eix:November2018WildfiresMembereix:SEDSettlementMembereix:SouthernCaliforniaEdisonCompanyMember2021-10-012021-10-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:CreekFireMember2017-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:CreekFireMember2017-12-012017-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SaddleRidgeFireMember2019-10-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:BobcatFireMember2020-09-300000827052eix:BobcatFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:HomeResidentialMember2020-09-300000827052eix:BobcatFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:CommercialPropertyMember2020-09-300000827052eix:BobcatFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:MinorStructuresMember2020-09-300000827052eix:SouthernCaliforniaEdisonCompanyMembereix:BobcatFireMember2020-09-012020-09-300000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SilveradoFireMember2020-10-310000827052eix:SilveradoFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:OtherStructuresMember2020-10-310000827052eix:SilveradoFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:AvocadoOrchardMember2020-10-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SilveradoFireMember2020-10-012020-10-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SilveradoFireMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:CoastalFireMember2022-05-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:CoastalFireMember2022-05-012022-05-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:FairviewFireMember2022-09-300000827052eix:FairviewFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:HomeResidentialMember2022-09-300000827052eix:FairviewFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:MinorStructuresMember2022-09-300000827052eix:SouthernCaliforniaEdisonCompanyMembereix:FairviewFireMember2022-09-012022-09-300000827052eix:SouthernCaliforniaEdisonCompanyMembereix:FairviewFireMember2025-03-012025-03-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:EatonFireMember2025-01-310000827052eix:EatonFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:SingleResidenceMember2025-01-310000827052eix:EatonFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:OtherMinorStructuresMember2025-01-310000827052eix:EatonFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:MultipleResidencesMember2025-01-310000827052eix:EatonFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:MixedCommercialResidentialAndNonresidentialCommercialStructuresMember2025-01-310000827052eix:EatonFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:ResidentialStructureMember2025-01-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:EatonFireMember2025-01-012025-01-310000827052eix:EatonFireMembereix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SubsequentEventMember2026-02-110000827052eix:EatonFireMembereix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SubsequentEventMember2026-02-112026-02-110000827052eix:EatonFireMembereix:SouthernCaliforniaEdisonCompanyMembereix:FederalEnergyRegulatoryCommissionMemberMember2025-01-012025-12-310000827052eix:A20172018WildfireMudslideEventsMember2019-07-012025-12-310000827052eix:A20172018WildfireMudslideEventsMember2025-01-012025-12-310000827052eix:A20172018WildfireMudslideEventsMember2024-01-012024-12-310000827052eix:A20172018WildfireMudslideEventsMember2023-01-012023-12-310000827052eix:OtherWildfireEventsMember2019-07-012025-12-310000827052eix:OtherWildfireEventsMember2025-01-012025-12-310000827052eix:OtherWildfireEventsMember2024-01-012024-12-310000827052eix:OtherWildfireEventsMember2023-01-012023-12-310000827052eix:EatonFireMember2019-07-012025-12-310000827052eix:EatonFireMember2025-01-012025-12-310000827052eix:EatonFireMember2024-01-012024-12-310000827052eix:EatonFireMember2023-01-012023-12-3100008270522019-07-012025-12-310000827052eix:A20172018WildfireMudslideEventsMember2024-12-310000827052eix:OtherWildfireEventsMember2024-12-310000827052eix:EatonFireMember2024-12-310000827052eix:A20172018WildfireMudslideEventsMember2025-12-310000827052eix:OtherWildfireEventsMember2025-12-310000827052eix:EatonFireMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A20172018WildfireMudslideEventsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherWildfireEventsMember2024-12-310000827052us-gaap:SettledLitigationMembereix:A20172018WildfireMudslideEventsMember2025-12-310000827052eix:SEDSettlementMembereix:A20172018WildfireMudslideEventsMember2025-12-310000827052us-gaap:SettledLitigationMembereix:A20172018WildfireMudslideEventsMember2024-12-310000827052eix:SEDSettlementMembereix:A20172018WildfireMudslideEventsMember2024-12-310000827052eix:SEDSettlementMembereix:A20172018WildfireMudslideEventsMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A20172018WildfireMudslideEventsMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherWildfireEventsRelatedClaimsMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A20172018WildfireMudslideEventsMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherWildfireEventsRelatedClaimsMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A20172018WildfireMudslideEventsMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:OtherWildfireEventsRelatedClaimsMember2023-01-012023-12-310000827052us-gaap:SubsidiaryOfCommonParentMember2025-01-012025-12-310000827052us-gaap:SubsidiaryOfCommonParentMembereix:WildfireClaimsMember2025-01-012025-12-310000827052us-gaap:SubsidiaryOfCommonParentMembereix:LegalCostsMember2025-01-012025-12-310000827052us-gaap:SubsidiaryOfCommonParentMember2024-01-012024-12-310000827052us-gaap:SubsidiaryOfCommonParentMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A20172018WildfireMudslideEventsAndTheOtherWildfireEventsMember2019-01-012025-09-300000827052eix:InsuranceRecoveriesMembereix:A20172018WildfireMudslideEventsMember2025-01-012025-12-310000827052eix:InsuranceRecoveriesMembereix:OtherWildfireEventsMember2025-01-012025-12-310000827052eix:InsuranceRecoveriesMembereix:EatonFireMember2025-01-012025-12-310000827052eix:InsuranceRecoveriesMember2025-01-012025-12-310000827052eix:CustomerFundedWildfireSelfInsuranceMembereix:A20172018WildfireMudslideEventsMember2025-01-012025-12-310000827052eix:CustomerFundedWildfireSelfInsuranceMembereix:OtherWildfireEventsMember2025-01-012025-12-310000827052eix:CustomerFundedWildfireSelfInsuranceMembereix:EatonFireMember2025-01-012025-12-310000827052eix:CustomerFundedWildfireSelfInsuranceMember2025-01-012025-12-310000827052eix:WildfireFundRecoveriesMembereix:A20172018WildfireMudslideEventsMember2025-01-012025-12-310000827052eix:WildfireFundRecoveriesMembereix:OtherWildfireEventsMember2025-01-012025-12-310000827052eix:WildfireFundRecoveriesMembereix:EatonFireMember2025-01-012025-12-310000827052eix:WildfireFundRecoveriesMember2025-01-012025-12-310000827052eix:FERCRecoveriesMembereix:A20172018WildfireMudslideEventsMember2025-01-012025-12-310000827052eix:FERCRecoveriesMembereix:OtherWildfireEventsMember2025-01-012025-12-310000827052eix:FERCRecoveriesMembereix:EatonFireMember2025-01-012025-12-310000827052eix:FERCRecoveriesMember2025-01-012025-12-310000827052eix:CPUCRMBARecoveriesMembereix:A20172018WildfireMudslideEventsMember2025-01-012025-12-310000827052eix:CPUCRMBARecoveriesMembereix:OtherWildfireEventsMember2025-01-012025-12-310000827052eix:CPUCRMBARecoveriesMembereix:EatonFireMember2025-01-012025-12-310000827052eix:CPUCRMBARecoveriesMember2025-01-012025-12-310000827052eix:CPUCWEMADeferralMembereix:A20172018WildfireMudslideEventsMember2025-01-012025-12-310000827052eix:CPUCWEMADeferralMembereix:OtherWildfireEventsMember2025-01-012025-12-310000827052eix:CPUCWEMADeferralMembereix:EatonFireMember2025-01-012025-12-310000827052eix:CPUCWEMADeferralMember2025-01-012025-12-310000827052eix:ShortTermReceivablesFromCustomerFundedWildfireSelfInsuranceMembereix:A20172018WildfireMudslideEventsMember2025-12-310000827052eix:ShortTermReceivablesFromCustomerFundedWildfireSelfInsuranceMembereix:OtherWildfireEventsMember2025-12-310000827052eix:ShortTermReceivablesFromCustomerFundedWildfireSelfInsuranceMembereix:EatonFireMember2025-12-310000827052eix:ShortTermReceivablesFromCustomerFundedWildfireSelfInsuranceMember2025-12-310000827052eix:LongTermInsuranceReceivablesMembereix:A20172018WildfireMudslideEventsMember2025-12-310000827052eix:LongTermInsuranceReceivablesMembereix:OtherWildfireEventsMember2025-12-310000827052eix:LongTermInsuranceReceivablesMembereix:EatonFireMember2025-12-310000827052eix:LongTermInsuranceReceivablesMember2025-12-310000827052eix:LongTermReceivablesFromWildfireFundRecoveriesMembereix:A20172018WildfireMudslideEventsMember2025-12-310000827052eix:LongTermReceivablesFromWildfireFundRecoveriesMembereix:OtherWildfireEventsMember2025-12-310000827052eix:LongTermReceivablesFromWildfireFundRecoveriesMembereix:EatonFireMember2025-12-310000827052eix:LongTermReceivablesFromWildfireFundRecoveriesMember2025-12-310000827052eix:FERCRelatedBalancingAccountsMembereix:A20172018WildfireMudslideEventsMember2025-12-310000827052eix:FERCRelatedBalancingAccountsMembereix:OtherWildfireEventsMember2025-12-310000827052eix:FERCRelatedBalancingAccountsMembereix:EatonFireMember2025-12-310000827052eix:FERCRelatedBalancingAccountsMember2025-12-310000827052eix:CPUCRegulatoryAssetsMembereix:A20172018WildfireMudslideEventsMember2025-12-310000827052eix:CPUCRegulatoryAssetsMembereix:OtherWildfireEventsMember2025-12-310000827052eix:CPUCRegulatoryAssetsMembereix:EatonFireMember2025-12-310000827052eix:CPUCRegulatoryAssetsMember2025-12-310000827052eix:LongTermInsuranceReceivablesMembereix:A20172018WildfireMudslideEventsMember2024-12-310000827052eix:LongTermInsuranceReceivablesMembereix:OtherWildfireEventsMember2024-12-310000827052eix:LongTermInsuranceReceivablesMember2024-12-310000827052eix:FERCRelatedBalancingAccountsMembereix:A20172018WildfireMudslideEventsMember2024-12-310000827052eix:FERCRelatedBalancingAccountsMembereix:OtherWildfireEventsMember2024-12-310000827052eix:FERCRelatedBalancingAccountsMember2024-12-310000827052eix:CPUCRegulatoryAssetsMembereix:A20172018WildfireMudslideEventsMember2024-12-310000827052eix:CPUCRegulatoryAssetsMembereix:OtherWildfireEventsMember2024-12-310000827052eix:CPUCRegulatoryAssetsMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:November2018WildfiresMember2025-01-012025-12-310000827052eix:A20172018WildfireMudslideEventsMembereix:AggregateMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:CreekFireMember2025-01-012025-12-310000827052eix:InsuranceForThePeriodJune12019ThroughJune302020Membereix:SouthernCaliforniaEdisonCompanyMember2019-06-012020-06-300000827052eix:InsuranceForThePeriodJuly12020ThroughJune302021Membereix:SouthernCaliforniaEdisonCompanyMember2020-07-012021-06-300000827052eix:InsuranceForThePeriodJuly12021ThroughJune302022Membereix:SouthernCaliforniaEdisonCompanyMember2021-07-012022-06-300000827052eix:InsuranceForThePeriodJuly12022ThroughJune302023Membereix:SouthernCaliforniaEdisonCompanyMember2022-07-012023-06-300000827052eix:WildfiresIgnitedBetweenJanuary12025AndDecember312025Membereix:SouthernCaliforniaEdisonCompanyMember2022-07-012023-06-300000827052eix:WildfiresIgnitedBetweenJanuary12026AndDecember312026Membereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:WildfiresIgnitedBetweenJanuary12026AndDecember312026Membereix:SouthernCaliforniaEdisonCompanyMember2022-07-012023-06-300000827052eix:SouthernCaliforniaEdisonCompanyMember2022-07-012023-06-300000827052eix:CommercialInsuranceCarriersMembereix:SouthernCaliforniaEdisonCompanyMember2022-07-012023-06-300000827052eix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-03-310000827052us-gaap:SubsidiaryOfCommonParentMembereix:SouthernCaliforniaEdisonCompanyMembereix:WildfireLiabilityInsuranceMember2023-01-012023-12-310000827052us-gaap:SubsidiaryOfCommonParentMembereix:SouthernCaliforniaEdisonCompanyMembereix:WildfireLiabilityInsuranceMember2024-01-012024-12-310000827052eix:CustomerFundedSelfInsuranceMembereix:SouthernCaliforniaEdisonCompanyMember2024-07-012024-07-310000827052us-gaap:SubsidiaryOfCommonParentMembereix:SouthernCaliforniaEdisonCompanyMembereix:WildfireLiabilityInsuranceMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:ThomasKoenigsteinFiresAndMontecitoMudslidesMember2019-01-012024-05-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:ThomasAndKoenigsteinFiresAndMontecitoMudslidesTKMMember2019-01-012024-05-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:ThomasAndKoenigsteinFiresAndMontecitoMudslidesMember2019-01-012024-05-310000827052eix:ThomasKoenigsteinFiresAndMontecitoMudslidesMembereix:SEDSettlementMembereix:SouthernCaliforniaEdisonCompanyMember2019-01-012024-05-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:ThomasAndKoenigsteinFiresAndMontecitoMudslidesMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:ThomasAndKoenigsteinFiresAndMontecitoMudslidesMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:WoolseySubrogationSettlementMember2025-12-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:WoolseySubrogationSettlementMember2025-05-312025-05-310000827052eix:WoolseySubrogationSettlementMembereix:SEDSettlementMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:WoolseySubrogationSettlementMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:MaterialSitesMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:MaterialSitesMember2025-01-012025-12-310000827052eix:MaterialSitesMembereix:SanOnofreMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:ImmaterialSitesMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:ImmaterialSitesMember2025-01-012025-12-310000827052eix:SanOnofreMember2025-01-012025-12-310000827052eix:PaloVerdeNuclearMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanySanOnofreAndPaloVerdeMember2025-01-012025-01-010000827052eix:SouthernCaliforniaEdisonCompanyMembereix:PaloVerdeNuclearMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SanOnofreMember2025-01-012025-12-310000827052eix:PowerPurchaseAgreementMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:PowerPurchaseAgreementMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:OfficeLeasesMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:OfficeLeasesMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:OtherOperatingLeasesMembersrt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:OtherOperatingLeasesMembersrt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:PPAOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:OtherOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:PPAOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:PPAOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:PPAOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2023-01-012023-12-310000827052eix:OtherOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:OtherOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:OtherOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2023-01-012023-12-310000827052eix:PPAOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:PPAOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2023-12-310000827052eix:OtherOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2024-12-310000827052eix:OtherOperatingLeasesMembereix:SouthernCaliforniaEdisonCompanyMember2023-12-310000827052srt:MinimumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052srt:MaximumMembereix:SouthernCaliforniaEdisonCompanyMember2025-12-310000827052eix:A2026RepurchaseProgramMember2025-12-310000827052eix:A2024RepurchaseProgramMember2024-07-310000827052eix:A2024RepurchaseProgramMember2024-12-310000827052eix:A2025RepurchaseProgramMember2024-12-310000827052eix:A2025RepurchaseProgramMember2025-12-310000827052us-gaap:PreferredStockMember2025-12-310000827052us-gaap:SeriesAPreferredStockMember2025-12-012025-12-310000827052us-gaap:SeriesBPreferredStockMember2025-12-012025-12-310000827052us-gaap:SeriesAPreferredStockMemberus-gaap:SubsequentEventMember2026-02-100000827052eix:SouthernCaliforniaEdisonCompanyMembereix:CumulativePreferredStock100DollarsParValueMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:CumulativePreferredStock25DollarsParValueMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:NoParValueMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SeriesGPreferredStockMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SeriesGPreferredStockMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SeriesGPreferredStockMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SeriesGPreferredStockMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SeriesJPreferredStockMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SeriesJPreferredStockMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SeriesJPreferredStockMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:SeriesJPreferredStockMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A5.45SeriesKPreferredStockMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A5.45SeriesKPreferredStockMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A5.45SeriesKPreferredStockMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A5.45SeriesKPreferredStockMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A5.00SeriesLPreferredStockMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A5.00SeriesLPreferredStockMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A5.00SeriesLPreferredStockMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A5.00SeriesLPreferredStockMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A7.50SeriesMPreferredStockMember2025-01-012025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A7.50SeriesMPreferredStockMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A7.50SeriesMPreferredStockMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A7.50SeriesMPreferredStockMember2024-12-310000827052eix:A6.95SeriesNPreferredStockMember2025-01-012025-12-310000827052eix:A6.95SeriesNPreferredStockMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A6.95SeriesNPreferredStockMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMembereix:A6.95SeriesNPreferredStockMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2024-01-012024-12-310000827052eix:SeriesKPreferredStockMember2025-01-012025-12-310000827052eix:EdisonInternationalParentAndOtherMember2025-01-012025-12-310000827052eix:EdisonInternationalParentAndOtherMember2024-01-012024-12-310000827052eix:EdisonInternationalParentAndOtherMember2023-01-012023-12-310000827052us-gaap:CommonStockMember2025-12-310000827052us-gaap:CommonStockMember2024-12-310000827052us-gaap:CommonStockMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:CommonStockMember2025-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:CommonStockMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:CommonStockMember2023-12-310000827052us-gaap:PreferredStockMember2024-12-310000827052us-gaap:PreferredStockMember2023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:PreferredStockMember2023-12-310000827052eix:PollutionControlBondsRedeemedAt2.625Member2024-12-310000827052eix:PollutionControlBondsRedeemedAt2.625Member2025-12-310000827052eix:PollutionControlBondsRedeemedAt2.625Member2023-12-310000827052eix:PollutionControlBondsRedeemedAt2.625Member2025-01-012025-12-310000827052eix:PollutionControlBondsRedeemedAt2.625Member2024-01-012024-12-310000827052eix:PollutionControlBondsRedeemedAt2.625Member2023-01-012023-12-310000827052eix:PollutionControlBondsRedeemedAt2.625Membereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:PollutionControlBondsRedeemedAt2.625Membereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:PollutionControlBondsRedeemedAt2.625Membereix:SouthernCaliforniaEdisonCompanyMember2023-01-012023-12-310000827052eix:PollutionControlBondsRemarketedAt4.50Member2025-12-310000827052eix:PollutionControlBondsRemarketedAt4.50Member2023-12-310000827052eix:PollutionControlBondsRemarketedAt4.50Member2024-12-310000827052eix:PollutionControlBondsRemarketedAt4.50Member2025-01-012025-12-310000827052eix:PollutionControlBondsRemarketedAt4.50Member2024-01-012024-12-310000827052eix:PollutionControlBondsRemarketedAt4.50Member2023-01-012023-12-310000827052eix:PollutionControlBondsRemarketedAt4.50Membereix:SouthernCaliforniaEdisonCompanyMember2025-01-012025-12-310000827052eix:PollutionControlBondsRemarketedAt4.50Membereix:SouthernCaliforniaEdisonCompanyMember2024-01-012024-12-310000827052eix:PollutionControlBondsRemarketedAt4.50Membereix:SouthernCaliforniaEdisonCompanyMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMember2025-02-012025-02-280000827052us-gaap:SubsidiaryOfCommonParentMembereix:SouthernCaliforniaEdisonCompanyMembereix:WildfireLiabilityInsuranceMember2022-01-012022-12-310000827052us-gaap:SubsidiaryOfCommonParentMembereix:SouthernCaliforniaEdisonCompanyMembereix:WildfireLiabilityInsuranceMember2022-07-012023-06-300000827052us-gaap:SubsidiaryOfCommonParentMembereix:SouthernCaliforniaEdisonCompanyMembereix:WildfireLiabilityInsuranceMember2025-12-310000827052us-gaap:SubsidiaryOfCommonParentMembereix:SouthernCaliforniaEdisonCompanyMembereix:WildfireLiabilityInsuranceMember2024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SubsidiaryOfCommonParentMember2024-01-012024-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SubsidiaryOfCommonParentMember2023-01-012023-12-310000827052eix:SouthernCaliforniaEdisonCompanyMemberus-gaap:SubsidiaryOfCommonParentMember2025-01-012025-12-310000827052us-gaap:SubsidiaryOfCommonParentMembereix:SouthernCaliforniaEdisonCompanyMembereix:PoweringProgressFoundationMember2025-01-012025-12-310000827052us-gaap:SubsidiaryOfCommonParentMembereix:SouthernCaliforniaEdisonCompanyMembereix:PoweringProgressFoundationMember2024-01-012024-12-310000827052us-gaap:SubsidiaryOfCommonParentMembereix:SouthernCaliforniaEdisonCompanyMembereix:PoweringProgressFoundationMember2023-01-012023-12-310000827052eix:PeterTaylorMember2025-10-012025-12-3100008270522025-10-012025-12-310000827052eix:PeterTaylorMember2025-12-310000827052srt:ParentCompanyMember2025-12-310000827052srt:ParentCompanyMember2024-12-310000827052srt:ParentCompanyMember2025-01-012025-12-310000827052srt:ParentCompanyMember2024-01-012024-12-310000827052srt:ParentCompanyMember2023-01-012023-12-310000827052srt:ParentCompanyMember2023-12-310000827052srt:ParentCompanyMember2022-12-310000827052eix:A5.75SeniorNotesDue2027Membersrt:ParentCompanyMember2025-12-310000827052eix:A4.125SeniorNotesDue2028Membersrt:ParentCompanyMember2025-12-310000827052eix:A5.25SeniorNotesDue2028Membersrt:ParentCompanyMember2025-12-310000827052eix:A6.95PercentageSeniorNotesDueIn2029Membersrt:ParentCompanyMember2025-12-310000827052eix:A5.45SeniorNoteDue2029Membersrt:ParentCompanyMember2025-12-310000827052eix:A6.25SeniorNoteDue2030Membersrt:ParentCompanyMember2025-12-310000827052eix:A5.25SeniorNotesDue2032Membersrt:ParentCompanyMember2025-12-310000827052eix:A8.125JuniorSubordinatedNotesDue2053Membersrt:ParentCompanyMember2025-12-310000827052eix:A7.875PercentageJuniorSubordinatedNotesDueIn2054Membersrt:ParentCompanyMember2025-12-310000827052srt:ParentCompanyMemberus-gaap:RelatedPartyMember2024-01-012024-12-310000827052srt:ParentCompanyMemberus-gaap:RelatedPartyMember2023-01-012023-12-310000827052srt:ParentCompanyMemberus-gaap:RelatedPartyMember2025-01-012025-12-310000827052srt:ParentCompanyMemberus-gaap:RelatedPartyMember2025-12-310000827052srt:ParentCompanyMemberus-gaap:RelatedPartyMember2024-12-31
Table of Contents

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
☑ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year endedDecember 31, 2025
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
Commission
File Number
Exact Name of Registrant
as specified in its charter
State or Other Jurisdiction of
Incorporation or Organization
IRS Employer
Identification Number
1-9936EDISON INTERNATIONALCalifornia95-4137452
1-2313SOUTHERN CALIFORNIA EDISON COMPANYCalifornia95-1240335
EDISON INTERNATIONALSOUTHERN CALIFORNIA EDISON COMPANY
2244 Walnut Grove Avenue2244 Walnut Grove Avenue
(P.O. Box 976)(P.O. Box 800)
Rosemead, CA 91770
Rosemead, CA 91770
(Address of principal executive offices)(Address of principal executive offices)
(626) 302-2222
(626) 302-1212
(Registrant's telephone number, including area code)(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Edison International:
Title of each classTrading Symbol(s)Name of each exchange on which registered
Common Stock, no par valueEIXNYSE LLC
Southern California Edison Company: None
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
Edison International 
Yes þ No ☐
 Southern California Edison Company 
Yes þ No ☐
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act.
Edison International 
Yes ☐ No þ
 Southern California Edison Company 
Yes ☐ No þ
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.
Edison International 
Yes þ No ☐
 Southern California Edison Company 
Yes þ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Edison International 
Yes þ No ☐
 Southern California Edison Company 
Yes þ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act. (Check One):
Edison InternationalLarge Accelerated FilerAccelerated Filer Non-accelerated Filer Smaller Reporting Company Emerging growth company
☑☐☐☐☐
Southern California Edison CompanyLarge Accelerated Filer Accelerated Filer Non-accelerated Filer Smaller Reporting Company Emerging growth company
☐☐☑☐☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
Edison International ☐ Southern California Edison Company ☐
Indicate by check mark whether the registrant has filed a report on and attestation to its management's assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C 7262(b)) by the registered public accounting firm that prepared or issued its audit report.
Edison International ☑ Southern California Edison Company ☐
If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements.
Edison International ☐ Southern California Edison Company ☐
Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to §240.10D-1(b).
Edison International ☐ Southern California Edison Company ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Edison International 
Yes ☐ No þ
 Southern California Edison Company 
Yes ☐ No þ
Aggregate market value of voting and non-voting common equity held by non-affiliates of the registrants as of June 30, 2025, the last business day of the most recently completed second fiscal quarter:
Edison International 
Approximately $19.8 billion
 Southern California Edison Company 
Wholly owned by Edison International
Indicate the number of shares outstanding of each of the registrant's classes of common stock, as of the latest practicable date:
Common Stock outstanding as of February 11, 2026:
Edison International384,790,927shares
Southern California Edison Company434,888,104shares (wholly owned by Edison International)
OMISSION OF CERTAIN INFORMATION
Southern California Edison Company meets the conditions set forth in General Instruction I(1)(a) and (b) of Form 10-K and is therefore filing this Form with the reduced disclosure format allowed under the General Instruction.
DOCUMENTS INCORPORATED BY REFERENCE
Designated portions of the Edison International Proxy Statement relating to Edison International's 2026 Annual Meeting of Shareholders are incorporated by reference into Part III of this report.

Table of Contents
TABLE OF CONTENTS
SEC Form 10-K
Reference Number
GLOSSARY
v
FORWARD-LOOKING STATEMENTS
1
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
3
Part II, Item 7
MANAGEMENT OVERVIEW
3
Highlights of Operating Results
3
Electricity Industry Trends
5
Cost of Capital Application
7
Capital Program
7
Southern California Wildfires and Mudslides
8
RESULTS OF OPERATIONS
11
Southern California Edison Company
11
Impact of the 2025 GRC
11
Years ended December 31, 2025 and 2024
13
2025 vs 2024
13
Edison International Parent and Other
15
Loss from Operations
16
LIQUIDITY AND CAPITAL RESOURCES
16
Southern California Edison Company
16
Available Liquidity
17
Regulatory Proceedings
17
Capital Investment Plan
18
Decommissioning of San Onofre
19
Margin and Collateral Deposits
20
Edison International Parent and Other
21
Edison International Income Taxes
22
Historical Cash Flows
22
Southern California Edison Company
22
Edison International Parent and Other
25
Contractual Obligations and Contingencies
26
Contractual Obligations
26
Contingencies
26
Off-Balance Sheet Arrangements
26
MARKET RISK EXPOSURES
26
Interest Rate Risk
26
Commodity Price Risk
27
Investment Price Risk
27
Credit Risk
28
CRITICAL ACCOUNTING ESTIMATES AND POLICIES
28
Accounting for Contingencies
28
Rate Regulated Enterprises
29
Income Taxes
30
Nuclear Decommissioning – Asset Retirement Obligation
31
i
Table of Contents
Pensions and Postretirement Benefits Other than Pensions
32
Contributions to the Wildfire Fund
33
NEW ACCOUNTING GUIDANCE
34
RISK FACTORS
34
Part I, Item 1A
RISKS RELATING TO EDISON INTERNATIONAL
34
RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY
34
Regulatory and Legislative Risks
34
Operating Risks
36
Financing Risks
39
Competitive and Market Risks
40
RISKS RELATING TO EDISON INTERNATIONAL AND SOUTHERN CALIFORNIA EDISON COMPANY
40
Cybersecurity and Physical Security Risks
40
Global and Regional Risks
42
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
42
Part II, Item 7A
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
42
Part II, Item 8
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM (PCAOB ID 238)
43
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM (PCAOB ID 238)
46
CONSOLIDATED FINANCIAL STATEMENTS
48
Consolidated Statements of Income for Edison International
48
Consolidated Statements of Comprehensive Income for Edison International
49
Consolidated Balance Sheets for Edison International
50
Consolidated Statements of Cash Flows for Edison International
52
Consolidated Statements of Changes in Equity for Edison International
53
Consolidated Statements of Income for Southern California Edison Company
55
Consolidated Statements of Comprehensive Income for Southern California Edison Company
55
Consolidated Balance Sheets for Southern California Edison Company
56
Consolidated Statements of Cash Flows for Southern California Edison Company
58
Consolidated Statements of Changes in Equity for Southern California Edison Company
59
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
60
Note 1. Summary of Significant Accounting Policies
60
Note 2. Property, Plant and Equipment
71
Note 3. Variable Interest Entities
71
Note 4. Fair Value Measurements
72
Note 5. Debt and Credit Agreements
76
Note 6. Derivative Instruments
77
Note 7. Revenue
79
Note 8. Income Taxes
80
Note 9. Compensation and Benefit Plans
84
Note 10. Investments
97
Note 11. Regulatory Assets and Liabilities
97
ii
Table of Contents
Note 12. Commitments and Contingencies
101
Note 13. Leases
114
Note 14. Equity
115
Note 15. Other Income, Net
118
Note 16. Supplemental Cash Flows Information
118
Note 17. Related-Party Transactions
118
120
Part II, Item 9
CONTROLS AND PROCEDURES
120
Part II, Item 9A
BUSINESS
121
Part I, Item 1
CORPORATE STRUCTURE, INDUSTRY AND OTHER INFORMATION
121
Subsidiaries of Edison International
121
Regulation of Edison International as a Holding Company
121
Human Capital
122
Insurance
124
SOUTHERN CALIFORNIA EDISON COMPANY
124
Regulation
124
Overview of Ratemaking Process
126
Purchased Power and Fuel Supply
128
Competition
129
Properties
131
Seasonality
131
SOUTHERN CALIFORNIA WILDFIRES
131
Recovery of Wildfire-Related Costs
132
Safety Certification and Wildfire Mitigation Plan
134
Public Safety Power Shutoffs
134
ENVIRONMENTAL CONSIDERATIONS
135
Greenhouse Gas Regulation
135
Environmental Risks
136
UNRESOLVED STAFF COMMENTS
136
Part I, Item 1B
CYBERSECURITY
136
Part I, Item 1C
PROPERTIES
137
Part I, Item 2
LEGAL PROCEEDINGS
137
Part I, Item 3
2017/2018 Wildfire/Mudslide Events
137
Environmental Proceedings
138
MINE SAFETY DISCLOSURES
139
Part I, Item 4
CERTAIN INFORMATION ABOUT EDISON INTERNATIONAL
139
INFORMATION ABOUT OUR EXECUTIVE OFFICERS
139
Part I
DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
140
Part III, Item 10
EXECUTIVE COMPENSATION
141
Part III, Item 11
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
141
Part III, Item 12
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
141
Part III, Item 13
PRINCIPAL ACCOUNTANT FEES AND SERVICES
141
Part III, Item 14
iii
Table of Contents
MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
143
Part II, Item 5
Edison International
143
Southern California Edison Company
143
Purchases of Equity Securities by Edison International and Affiliated Purchasers
143
Comparison of Five-Year Cumulative Total Return
144
OTHER INFORMATION
144
Part II, Item 9B
Part II, Item 6
Insider Trading Arrangements
144
FORM 10-K SUMMARY
144
Part IV, Item 16
DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
144
Part II, Item 9C
EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
145
Part IV, Item 15
EXHIBIT INDEX
146
SCHEDULES SUPPLEMENTING FINANCIAL STATEMENTS
152
SIGNATURES
157
This combined Form 10-K is separately filed by Edison International and SCE. Information contained in this document relating to SCE is filed by Edison International and separately by SCE. SCE makes no representation as to information relating to Edison International or its subsidiaries, except as it may relate to SCE and its subsidiaries.
iv
Table of Contents
GLOSSARY
The following terms and abbreviations appearing in the text of this report have the meanings indicated below.
2017/2018 Wildfire/Mudslide Eventsthe Thomas Fire, the Koenigstein Fire, the Montecito Mudslides and the Woolsey Fire, collectively
AB 1054California Assembly Bill 1054, executed by the governor of California on July 12, 2019
AB 1054 Excluded Capital Expenditures$1.6 billion in wildfire risk mitigation capital expenditures that SCE has excluded from the equity portion of SCE's rate base as required under AB 1054
ARO(s)asset retirement obligation(s)
CAISOCalifornia Independent System Operator
Cal Advocates
the California Public Advocates Office
CAL FIRE
the California Department of Forestry and Fire Protection
CAL OES
the California Governor's Office of Emergency Services
California Wildfire Legislation
AB 1054 and SB 254, collectively
Capital Structure Compliance Period
January 1, 2026 to December 31, 2028, the current compliance period for SCE's CPUC authorized capital structure
CCAscommunity choice aggregators which are cities, counties, and certain other public agencies with the authority to generate and/or purchase electricity for their local residents and businesses
Continuation Account
a new account within the Wildfire Fund established under SB 254 that may be available for fires ignited on or after the SB 254 Effective Date
CPUCCalifornia Public Utilities Commission
DARTa Days Away Restricted or Transferred incident, which is a work-related Occupational Safety and Health Administration recordable injury or illness that results in days away from work, restricted duty or transfer of duties
DERsdistributed energy resources
DGCthe decommissioning general contractor engaged by SCE to undertake a significant scope of decommissioning activities at San Onofre
Eaton Fire
a wind-driven fire that originated in Los Angeles County in January 2025
Edison International Proxy Statement
Proxy Statement to be filed with the SEC in connection with Edison International's Annual Meeting of Shareholders expected to be held on April 23, 2026
EEI Serious Injurya work-related injury that is categorized as a "serious injury" by Edison Electric Institute
EEI SIFa work-related fatality or an EEI Serious Injury
EIS
Edison Insurance Services, Inc., a wholly-owned subsidiary of Edison International licensed to provide insurance to Edison International and its subsidiaries
Electric Service Provideran entity other than an investor-owned utility or CCA that provides electric power and ancillary services to retail customers
ERRAEnergy Resource Recovery Account
Fast curve settings
protective settings used to mitigate the risk of wildfires in high fire risk areas by increasing the speed with which a protective device reacts to most fault currents
FERCFederal Energy Regulatory Commission
FitchFitch Ratings, Inc.
GAAPgenerally accepted accounting principles in the United States
GHGgreenhouse gas
GRCgeneral rate case
Initial Account
an account within the Wildfire Fund established under AB 1054 available for fires ignited before the SB 254 Effective Date
IRAInflation Reduction Act of 2022
Koenigstein Firea wind-driven fire that originated near Koenigstein Road in the City of Santa Paula in Ventura County, California, on December 4, 2017
v
Table of Contents
LAFD
the Los Angeles Fire Department
Liability Cap
a cap on the aggregate requirement to reimburse the Wildfire Fund over a trailing three calendar year period which applies if certain conditions are met and is equal to 20% of the equity portion of the utility's transmission and distribution rate base, excluding general plant and intangibles, for the year of the applicable wildfire's ignition
MD&AManagement's Discussion and Analysis of Financial Condition and Results of Operations in this report
Montecito Mudslidesthe debris flows and flooding in Montecito, Santa Barbara County, California, that occurred in January 2018
Moody'sMoody's Investors Service, Inc.
MWMegawatt(s)
NDCTPNuclear Decommissioning Cost Triennial Proceeding, a CPUC proceeding to review decommissioning costs
NEMnet energy metering
NERCNorth American Electric Reliability Corporation
NRCUnited States Nuclear Regulatory Commission
OEISOffice of Energy Infrastructure Safety of the California Natural Resources Agency
Other Wildfire Events
Collectively, all the wildfires that originated in Southern California in and after 2017 but before 2025 where SCE's equipment has been or may be alleged to be associated with the fire's ignition, except for the Thomas Fire, the Koenigstein Fire and the Woolsey Fire
PABAPortfolio Allocation Balancing Account
Palo Verdenuclear electric generating facility located near Phoenix, Arizona in which SCE holds a 15.8% ownership interest
PBOP(s)postretirement benefits other than pension(s)
PG&EPacific Gas & Electric Company
PSPSPublic Safety Power Shutoff(s)
ROEreturn on common equity
RPSCalifornia's Renewables Portfolio Standard
S&PStandard & Poor's Financial Services LLC
Safety Tier 1 Contractorsindividuals assigned to contracted work activities that may be high risk and, without implementation of appropriate safety measures, may be potentially hazardous or life threatening
San Onofreretired nuclear generating facility located in south San Clemente, California in which SCE holds a 78.21% ownership interest
SB 254
California Senate Bill 254, executed by the governor of California on September 19, 2025
SB 254 Effective Date
September 19, 2025
SB 254 Excluded Capital Expenditures
$2.9 billion in wildfire risk mitigation capital expenditures, approved on or after January 1, 2026, that SCE expects it will be required to exclude from the equity portion of SCE's rate base as required under SB 254
SCESouthern California Edison Company, a wholly-owned subsidiary of Edison International
SDG&ESan Diego Gas & Electric Company
SECU.S. Securities and Exchange Commission
SEDSafety and Enforcement Division of the CPUC
SED Agreementan agreement dated October 21, 2021 between SCE and the SED regarding the 2017/2018 Wildfire/Mudslide Events and three other 2017 wildfires
SoCalGasSouthern California Gas Company
Thomas Firea wind-driven fire that originated in the Anlauf Canyon area of Ventura County, California, on December 4, 2017
TKMcollectively, the Thomas Fire, the Koenigstein Fire and the Montecito Mudslides
TKM Settlement Agreementa settlement agreement entered into between SCE and the California Public Advocates Office in August 2024 in the CPUC-jurisdictional rate recovery proceeding related to TKM
vi
Table of Contents
Trio
Edison Energy, LLC, an indirect wholly-owned non-utility subsidiary of Edison International doing business as "Trio"
Turnover Ratethe number of employees (other than interns) who leave Edison International Parent or SCE for voluntary or involuntary reasons, divided by the average number of employees during the relevant period
WMP
a wildfire mitigation plan required to be filed to describe a utility's plans to construct, operate, and maintain electrical lines and equipment that will help minimize the risk of catastrophic wildfires caused by such electrical lines and equipment
Wildfire Fund
the insurance fund established under AB 1054 and expanded under SB 254
Wildfire Recovery Compensation Program
a program designed to enable eligible individuals and businesses impacted by the Eaton Fire to seek expedited resolution of their claims, launched by SCE in the fall of 2025
Woolsey Firea wind-driven fire that originated in Ventura County in November 2018
Woolsey Settlement Agreement
a settlement agreement entered into between SCE and intervenors in September 2025 in the CPUC-jurisdictional rate recovery proceeding related to the Woolsey Fire
vii
Table of Contents
FORWARD-LOOKING STATEMENTS
This Annual Report on Form 10-K contains "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements reflect Edison International's and SCE's current expectations and projections about future events based on Edison International's and SCE's knowledge of present facts and circumstances and assumptions about future events and include any statements that do not directly relate to a historical or current fact. Other information distributed by Edison International and SCE that is incorporated in this report, or that refers to or incorporates this report, may also contain forward-looking statements. In this report and elsewhere, the words "expects," "believes," "anticipates," "estimates," "projects," "intends," "plans," "probable," "may," "will," "could," "would," "should," "targets," "preliminary," and variations of such words and similar expressions, or discussions of strategy or plans, are intended to identify forward-looking statements. Such statements necessarily involve risks and uncertainties that could cause actual results to differ materially from those anticipated. Some of the risks, uncertainties and other important factors that could cause results to differ from those currently expected, or that otherwise could impact Edison International and SCE, include, but are not limited to the:
•ability of SCE to recover its costs through regulated rates, timely or at all, including uninsured wildfire-related costs (including amounts paid for self-insured retention and co-insurance, and amounts not recoverable from the Wildfire Fund), and costs incurred for wildfire restoration efforts and to mitigate the risk of utility equipment causing future wildfires;
•the cybersecurity of Edison International's and SCE's critical information technology systems for grid control and business, employee and customer data, and the physical security of Edison International's and SCE's critical assets and personnel;
•risks associated with the construction, operation, and maintenance of electrical facilities, including worker, contractor, and public safety issues, the risk of utility assets causing or contributing to wildfires, failure, availability, efficiency, and output of equipment and facilities, and availability and cost of spare parts;
•impact of affordability of customer rates on SCE's ability to execute its strategy, including the impact of affordability on SCE's ability to obtain regulatory approval of, or cost recovery for, operations and maintenance expenses, proposed capital investment projects, forecasted load growth does not occur, and increased costs due to supply chain constraints, tariffs, inflation and rising interest rates and the impact of affordability on legislative actions;
•ability of SCE to update its grid infrastructure to maintain system integrity and reliability, and meet electrification needs;
•ability of SCE to implement its operational and strategic plans, including its WMP, its target energization times and capital investment program, including challenges related to project site identification, public opposition, environmental mitigation, construction, permitting, contractor performance, changes in the CAISO's transmission plans, and governmental approvals;
•risks of regulatory or legislative restrictions that would limit SCE's ability to implement operational measures to mitigate wildfire risk, including PSPS and fast curve settings, when conditions warrant or would otherwise limit SCE's operational practices relative to wildfire risk mitigation;
•ability of SCE to obtain safety certifications from OEIS;
•risk that the California Wildfire Legislation or anticipated new California legislation does not effectively mitigate the significant exposure faced by California investor-owned utilities related to liability for damages arising from catastrophic wildfires where utility facilities are alleged to be a substantial or contributing cause, including the longevity of the Wildfire Fund and the CPUC's interpretation of and actions under the California Wildfire Legislation, including its interpretation of the clarified prudency standard;
•ability of Edison International and SCE to effectively attract, manage, develop and retain a skilled workforce, including its contract workers;
•decisions and other actions by the CPUC, the FERC, the NRC, the California legislature and other governmental authorities, including decisions and actions related to nationwide or statewide crisis, approval of regulatory proceeding settlements, determinations of authorized rates of return or return on equity, the recoverability of wildfire-related and debris flow-related costs, issuance of SCE's wildfire safety certification, reforming wildfire-related liability protections available to California investor-owned utilities, wildfire mitigation efforts, approval and implementation of electrification programs, and delays in executive, regulatory and legislative actions;
1
Table of Contents
•governmental, statutory, regulatory, or administrative changes or initiatives affecting the electricity industry, including the market structure rules applicable to each market adopted by the NERC, CAISO, Western Electricity Coordinating Council, and similar regulatory bodies in adjoining regions, and changes in the United States' and California's environmental priorities that lessen the importance placed on GHG reduction and other climate related priorities;
•potential for penalties or disallowances for non-compliance with applicable laws and regulations, including fines, penalties and disallowances related to customer notifications and to wildfires where SCE's equipment is alleged to be associated with ignition;
•extreme weather-related incidents (including events caused, or exacerbated, by climate change), such as wildfires, debris flows, flooding, droughts, high wind events and extreme heat events and other natural disasters (such as earthquakes), which could cause, among other things, worker and public safety issues, property damage, outages and other operational issues (such as issues due to damaged infrastructure), PSPS activations and unanticipated costs;
•risks associated with the decommissioning of San Onofre, including those related to worker and public safety, public opposition, permitting, governmental approvals, on-site storage of spent nuclear fuel and other radioactive material, delays, contractual disputes, and cost overruns;
•risks associated with cost allocation resulting in higher rates for utility bundled service customers because of possible customer bypass or departure for other electricity providers such as CCAs and Electric Service Providers;
•actions by credit rating agencies to downgrade Edison International or SCE's credit ratings or to place those ratings on negative watch or negative outlook;
•ability of Edison International or SCE to borrow funds and access bank and capital markets on reasonable terms;
•changes in tax laws and regulations, at both the state and federal levels, or changes in the application of those laws, that could affect recorded deferred tax assets and liabilities, effective tax rates and cash flows;
•changes in rates of inflation (including whether inflation-related adjustments to SCE's authorized revenues allowed by the public utility regulators are commensurate with inflation rates), and changes in interest rates and potential future adjustments to SCE's ROE based on changes in Moody's utility bond rate index;
•availability and creditworthiness of counterparties and the resulting effects on liquidity in the power and fuel markets and/or the ability of counterparties to pay amounts owed in excess of collateral provided in support of their obligations; and
•cost of fuel for generating facilities and related transportation, which could be impacted by, among other things, disruption of natural gas storage facilities, to the extent not recovered, timely or at all, through regulated rate cost escalation provisions or balancing accounts.
Additional information about risks and uncertainties, including more detail about the factors described in this report, is contained throughout this report. Readers are urged to read this entire report, including information incorporated by reference, and carefully consider the risks, uncertainties, and other factors that affect Edison International's and SCE's businesses. Forward-looking statements speak only as of the date they are made and neither Edison International nor SCE are obligated to publicly update or revise forward-looking statements. Readers should review future reports filed by Edison International and SCE with the SEC. Edison International and SCE post or provide direct links to (i) certain SCE and other parties' regulatory filings and documents with the CPUC and the FERC and certain agency rulings and notices in open proceedings in a section titled "SCE Regulatory Highlights," (ii) certain documents and information related to Southern California wildfires which may be of interest to investors in a section titled "Southern California Wildfires," and (iii) presentations, documents and information that may be of interest to investors in a section titled "Presentations and Updates" at edisoninvestor.com in order to publicly disseminate such information. The reports, presentations, documents and information contained on, or connected to, the Edison International investor website are not deemed part of, and are not incorporated by reference into, this report.
Except when otherwise stated, references to each of Edison International or SCE mean each such company with its subsidiaries on a consolidated basis. References to "Edison International Parent and Other" mean Edison International Parent and its subsidiaries other than SCE and its subsidiaries and "Edison International Parent" mean Edison International on a stand-alone basis, not consolidated with its subsidiaries. Unless otherwise described, all the information contained in this report relates to both filers.
2
Table of Contents
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The discussion related to the changes in financial condition for 2024 compared to 2023 is incorporated by reference to Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations in Edison International's and SCE's combined Annual Report on Form 10-K for the year ended December 31, 2024, which was filed with the SEC in February 2025.
MANAGEMENT OVERVIEW
Highlights of Operating Results
Edison International is the ultimate parent holding company of SCE and Edison Energy, LLC, doing business as Trio. SCE is an investor-owned public utility primarily engaged in the business of supplying and delivering electricity to an approximately 50,000 square mile area across Southern, Central and Coastal California. Trio is a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial and institutional customers. Trio's business activities are currently not material to report as a separate business segment.
Edison International's earnings are prepared in accordance with GAAP. Management uses core earnings (loss) internally for financial planning and for analysis of performance. Core earnings (loss) are also used when communicating with investors and analysts regarding Edison International's earnings results to facilitate comparisons of the company's performance from period to period. Core earnings (loss) are a non-GAAP financial measure and may not be comparable to those of other companies. Core earnings (loss) are defined as earnings available to Edison International shareholders less non-core items. Non-core items include income or loss from discontinued operations and income or loss from significant discrete items that management does not consider representative of ongoing earnings, such as write downs, asset impairments and other income and expense related to changes in law, outcomes in tax, regulatory or legal proceedings, and exit activities, including sale of certain assets and other activities that are no longer continuing.
SCE implemented a customer-funded wildfire self-insurance program in July 2023. With the commencement of this program, Edison International and SCE no longer consider wildfire-related claim losses to be representative of ongoing earnings and treat such costs as non-core items.
3
Table of Contents
(in millions)20252024
2025 vs. 2024
Change
Net income (loss) available to Edison International
   
SCE$4,889 $1,619 $3,270 
Edison International Parent and Other(430)(335)(95)
Edison International4,459 1,284 3,175 
Less: Non-core items
SCE
2017/2018 Wildfire/Mudslide Events (claims and expenses), net of recoveries
2,961 (493)3,454 
Eaton Fire claims and expenses
(15)— (15)
Other Wildfire Events (claims and expenses), net of recoveries
(1)(162)161 
Wildfire Fund expense
(144)(146)2 
Net charges related to disallowed historical capital expenditures in SCE's 2025 GRC decision(76)— (76)
Severance costs, net of recovery— (50)50 
Income tax (expense) benefit1
(747)238 (985)
SCE non-core items
1,978 (613)2,591 
Edison International Parent and Other
Wildfire claims insured by EIS
(50)(4)(46)
Income tax benefit1
11 1 10 
Edison International Parent and Other non-core items
(39)(3)(36)
Total non-core items1,939 (616)2,555 
Core earnings (loss)
SCE2,911 2,232 679 
Edison International Parent and Other(391)(332)(59)
Edison International$2,520 $1,900 $620 
1SCE and Edison International Parent and Other non-core items are tax-effected at an estimated statutory rate of approximately 28%; wildfire claims insured by EIS insurance contract are tax-effected at the federal statutory rate of 21%.
Edison International's 2025 earnings increased $3,175 million, driven by an increase in SCE's earnings of $3,270 million, partially offset by an increase in Edison International Parent and Other loss of $95 million. SCE's higher net income consisted of $679 million of higher core earnings and $2,591 million of higher non-core earnings. Edison International Parent and Other's higher net loss consisted of $59 million of higher core loss and $36 million of higher non-core loss.
In January and December 2025, the CPUC approved the TKM Settlement Agreement and the Woolsey Settlement Agreement, respectively. As a result, in the year ended 2025, SCE recorded cost recoveries through CPUC electric rates authorized under both the TKM Settlement Agreement and the Woolsey Settlement Agreement. These cost recoveries are reflected either as core earnings or non-core items, as discussed below. This classification is consistent with the original classification when the respective costs were incurred.
The increase in SCE's core earnings in 2025 was primarily due to higher revenue from the 2025 GRC final decision and a benefit to interest expense related to cost recoveries authorized under the TKM and Woolsey Settlement Agreements. The increase in Edison International Parent and Other's core loss in 2025, was primarily due to higher interest expense and preferred stock redemption loss.
Consolidated non-core items for 2025 and 2024 for Edison International included:
•2017/2018 Wildfire/Mudslide Events claims and expenses, net of recoveries:
•Net earnings recorded in 2025 related to the TKM Settlement Agreement, including ongoing legal expenses: $1,341 million ($966 million after-tax) of claim costs and $55 million ($40 million after-tax) of legal expenses authorized for recovery, partially offset by shareholder-funded wildfire mitigation expenses of $50 million ($36 million after-tax) and impairment of incremental restoration-related assets of $8 million ($6 million after-tax).
4
Table of Contents
•Net earnings recorded in 2025 related to the Woolsey Settlement Agreement, including ongoing legal expenses: $1,603 million ($1,154 million after-tax) of claim costs and $35 million ($25 million after-tax) of legal expenses authorized for recovery, partially offset by impairment of incremental restoration-related assets of $10 million ($7 million after-tax).
•Charges of $5 million ($3 million after tax) recorded in 2025, and $493 million ($355 million after-tax) recorded in 2024, related to claim costs and related legal expenses, net of expected regulatory recoveries.
See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies" for further information.
•Eaton Fire claims and expenses:
•Charges of $15 million ($11 million after tax) recorded in 2025 primarily from the shareholder contribution related to SCE's customer-funded self-insurance coverage and legal and other expenses.
See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies" for further information.
•Other Wildfire Events claims and expenses, net of recoveries:
•Charges of $1 million ($1 million after-tax) recorded in 2025 consisted of $15 million of legal expenses, net of expected regulatory recoveries, partially offset by $14 million of insurance reimbursements for costs incurred in previous years.
•Charges of $162 million ($117 million after-tax) recorded in 2024 for wildfire claims and related legal expenses, net of expected insurance and regulatory recoveries.
See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies" for further information.
•Charges of $144 million ($104 million after-tax) recorded in 2025 and $146 million ($105 million after-tax) recorded in 2024 from the amortization of SCE's contributions to the Wildfire Fund. See "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies" for further information.
•Net charges of $76 million ($39 million after-tax) recorded in 2025, primarily related to the impairment of utility property, plant and equipment associated with historical capital expenditures disallowed in SCE's 2025 GRC final decision. See "Results of Operations —Impact of 2025 GRC" for further information.
•Severance costs of $50 million ($36 million after-tax), net of expected FERC recovery, recorded in 2024 due to reductions in workforce.
•Charges of $50 million ($39 million after-tax) recorded in 2025 and $4 million ($3 million after-tax) recorded in 2024, both related to wildfire claims insured by EIS. See "Notes to Consolidated Financial Statements— Note 12. Commitments and Contingencies" for further information.
See "Results of Operations" for discussion of SCE and Edison International Parent and Other results of operations.
Electricity Industry Trends
The electric power industry is undergoing urgent and fundamental changes in how energy infrastructure is planned and built, driven by new sources of demand, such as electric vehicles, data centers, and building electrification; technological innovations that support clean energy adoption, such as distributed generation and energy storage; and government actions to reduce GHG emissions. These factors, coupled with the increasing impacts of climate change, are altering the way in which electricity is generated and delivered. These changes are further amplified by rapidly rising electricity demand across the U.S. economy, which is reshaping investment needs and grid planning timelines.
Rising electricity demand across the U.S. economy is a primary force reshaping grid needs and investment planning. SCE projects electricity demand to nearly double between 2025 and 2045, driven by transportation electrification, new residential housing, and increases in commercial and industrial consumption. These economy-wide trends create broad customer and climate benefits by supporting long-term emissions reduction. Emerging market uncertainties, tighter resource timelines, and rising costs have increased the complexity of long‑term clean energy planning, adding pressure to California's climate goals. Despite this, California has demonstrated strong long-term support of transportation electrification. Edison International believes that more state policy support, along with public and private investment, is needed to enable California to reach its 2030 and 2045 GHG reduction targets. Additional policy and regulatory support is also needed to de-risk the development of clean firm resources, adjust planning processes to enable proactive grid build-
5
Table of Contents
out, and streamline permitting processes. The current federal administration has declared a national emergency on energy, stressing the need for a reliable, diversified, and affordable supply of energy. The integrity and expansion of energy infrastructure is an immediate and pressing priority.
In parallel, climate change impacts continue to intensify the need for system resilience and clean‑energy adoption. The impacts of climate change are apparent and accelerating. In 2024, the Earth experienced its hottest year on record. This spike in temperature is making extreme weather events commonplace. In California alone, climate-related disasters have cost the state tens of billions of dollars since 2018, with the 2025 wildfires being particularly devastating. Climate change is expected to have far-reaching effects on society, necessitating industry-wide solutions to enhance grid resilience and support a clean, reliable and affordable grid.
Recent federal actions have challenged clean energy standards and regulations in jurisdictions across the country. Rising customer cost pressures underscore the importance of enacting electricity policies and investment decisions that balance affordability while supporting a reliable and clean energy transition. California remains committed to reducing its GHG emissions, improving local air quality and supporting continued economic growth. The state codified into law goals to reduce GHG emissions by 40% from 1990 levels by 2030 and 85% from the same baseline by 2045, as well as to be carbon neutral by 2045. State and local air quality plans also call for substantial improvements including reducing smog-causing nitrogen oxides 90% below 2010 levels by 2032 in the most polluted areas of the state. State and local agencies continue to develop regulations that support the state's climate and clean air goals.
While these policy goals cannot be achieved by the electric sector alone, the electric grid is a critical enabler of the adoption of energy technologies that support California's GHG reduction objectives. California has set RPS targets which require California retail sellers of electricity to provide 60% of power from renewable resources by 2030. California also requires sellers of electricity to deliver 100% of retail sales from carbon-free sources by 2045, including interim targets of 90% by 2035 and 95% by 2040. Using preliminary estimates based on information available as of February 11, 2026, approximately 61% of SCE's customer deliveries in 2025 came from carbon-free resources. SCE continues to make progress towards meeting its long-term RPS and carbon-free power goals and interim targets. In addition, Edison International is committed to achieving net-zero GHG emissions by 2045, in alignment with economy-wide climate actions planned by California. This commitment covers the power SCE delivers to customers and Edison International's enterprise-wide operations. To further support these goals, Edison International and SCE are investing in building a more resilient grid to reduce climate- and weather-related vulnerabilities. Since 2018, SCE has been adapting to climate change through system hardening to reduce wildfire risk. SCE continues to make grid hardening investments approved in SCE's 2025 GRC to address wildfire risks. SCE is conducting ongoing analysis for wildfire and other climate adaptation vulnerabilities that will be presented in its 2026 climate adaptation vulnerability assessment.
Edison International believes that California's 2045 goals can be achieved most economically through emissions reductions enabled by clean electricity to serve 100% of retail sales, electrifying approximately 90% of light-duty vehicles, 90% of medium-duty vehicles, 54% of heavy-duty vehicles, 80% of buses and 95% of buildings. Additionally, reducing emissions to near zero in the electric sector relies on developing clean firm resources to replace natural gas. Clean firm resources, such as next-generation geothermal, small modular nuclear reactors, natural gas with carbon capture and storage, and clean hydrogen, produce constant power through any weather condition or season with little or no greenhouse gas emissions.
Edison International's vision is to lead the transformation of the electric power industry and the company is focused on opportunities in delivering clean energy, advancing electrification, building a modernized and more reliable grid, and enabling customers' technology choices. SCE's ongoing focus to drive operational and service excellence is intended to allow it to achieve these objectives safely while controlling costs and customer rates. SCE expects its bundled system average rate will rise at a compound annual growth rate equal to or below inflation through 2030. This projected rate growth incorporates the 2025 GRC approval and settlement of the cost recovery proceedings for the 2017/2018 Wildfire/Mudslide Events (See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides" for further information). Partially offsetting these increases are historical costs coming out of rates and rising electricity consumption. SCE projects that, even as electricity bills increase over time, total energy costs for the average SCE household will be reduced by approximately 40% by 2045 due to the adoption of energy-efficient electrified technologies among other drivers.
SCE’s investments in the grid, utility owned storage capacity, and contracts for substantial new clean energy resources are key enablers of reliable economy-wide electrification. See "—Capital Program," "Liquidity and Capital Resources—Capital Investment Plan," and "Business—SCE—Purchased Power and Fuel Supply—CAISO Wholesale Energy Market" for further details. SCE also continues to implement its transportation electrification programs. As of December 31, 2025, SCE had completed construction at 572 sites to support 9,761 charge ports under its suite of light-duty Charge Ready programs, and 132 sites to support the electrification of 2,859 medium and heavy-duty vehicles through its Charge Ready Transport program. More than 85% of SCE's planned capital investments are in its distribution grid and are essential to meeting grid reliability, resiliency, and readiness objectives, as discussed in "—Capital Program."
6
Table of Contents
Changes in the electric power industry are impacting customers and jurisdictions outside California as well. Many other states and countries are also pursuing climate change and GHG reduction objectives, and large commercial and industrial customers are continuing to pursue cost reduction and sustainability goals. Trio is a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial and institutional customers who may be impacted by these changes.
To better engage in this broader transformation and provide a view of developments outside of SCE, Edison International has also made several investments in emerging companies in areas related to the technology and business model changes that are driving industry transformation and may make additional investments in the future. These investments are not financially material to Edison International.
Cost of Capital Application
In December 2025, the CPUC issued a final decision on SCE's 2026 – 2028 cost of capital application that set SCE's ROE at 10.03%, and maintained SCE's current authorized capital structure, after CPUC-allowed exclusions, of 52% common equity, 43% long-term debt, and 5% preferred equity. Under the final decision, SCE's 2026 authorized cost of long-term debt and preferred equity are 4.71% and 6.89%, respectively. Based on the approved capital structure and costs, SCE's weighted average return on rate base for 2026 will be 7.59%. Based on the revenue requirement approved in SCE's 2025 GRC, the final decision will decrease SCE's revenue requirement in 2026 by approximately $51 million compared to the previously authorized cost of capital. The decision maintains the existing cost of capital adjustment mechanism. For information on the cost of capital adjustment mechanism, see "Business—SCE—Overview of Ratemaking Process."
Capital Program
Capital Expenditures
Total capital expenditures (including accruals) were $6.7 billion in 2025 and $5.7 billion in 2024.
SCE's capital expenditure forecast has been updated to reflect planned CPUC-jurisdictional spending as informed by the 2025 GRC final decision and expected FERC capital expenditures.
The table below reflects forecast capital expenditures for 2026 – 2030, based on authorized and planned CPUC-jurisdictional spending and current management expectations of FERC-jurisdictional spending. CPUC-jurisdictional spending includes amounts authorized in the 2025 GRC, and other planned non-GRC CPUC capital spending. Forecast expenditures for FERC capital projects are subject to change due to factors such as timeliness of permitting, licensing, regulatory approvals, contractor bids, supply chain issues, and other operational considerations.
Based on management's judgment of potential capital spending variability informed by historical precedent of previously authorized amounts, potential permitting delays, and other operational considerations, a range case was prepared reflecting reductions to CPUC non-GRC capital expenditures and FERC capital expenditures.
The following table sets forth a summary of capital expenditures for 2025 actual spend and a forecast for 2026 – 2030 on the basis described above:
(in billions)
2025
2026
2027
2028
20292030Total
2026 – 2030
Traditional capital expenditures     
Distribution$4.9$5.4$5.5$5.5$6.7$7.1$30.2
Transmission0.50.80.90.91.11.04.7
Generation0.20.20.20.20.30.21.1
Subtotal5.66.46.66.68.18.336.0
Wildfire mitigation-related capital expenditures1.10.91.01.00.90.84.6
Total capital expenditures$6.7$7.3$7.6$7.6$9.0$9.1$40.6
Total capital expenditures using range case discussed above
*$7.1$7.3$7.2$8.0$7.9$37.5
*Not applicable
7
Table of Contents
SCE intends to file an application with the CPUC in the first quarter of 2026 requesting capital expenditures of at least $3 billion to be spent between 2026 through 2033 for an advanced metering infrastructure program that supports improved grid management and customer benefits. Approximately half of the capital expenditures are included in the table above.
In addition, from 2022 to 2025, CAISO released its annual transmission plans approving projects to be constructed by SCE, with total anticipated capital expenditures of approximately $3 billion, of which approximately $1 billion is included in the table above. As part of its 2025-2026 Transmission Planning Process, CAISO is reassessing certain SCE projects from the 2022-2023 Transmission Plan and plans to provide its recommendation by May 2026.
Rate Base
SCE's year-end rate base was $48.2 billion at December 31, 2025, compared to $45.7 billion at December 31, 2024.
SCE's authorized CPUC-jurisdictional rate base is determined through the GRC and other regulatory proceedings. Differences between actual and CPUC-authorized rate base are addressed in subsequent GRCs or other regulatory proceedings. FERC-jurisdictional rate base is determined based on actual capital expenditures.
Reflected below is SCE's weighted average annual rate base for 2025 – 2030, based on the capital expenditure forecasts discussed above. In addition, the table below does not reflect the SB 254 Excluded Capital Expenditures, which SCE plans to recover through the issuance of securitized bonds. For further information, see "Business—Southern California Wildfires— Recovery of Wildfire-Related Costs—California Wildfire Legislation—Excluded Capital Expenditures."
(in billions)
2025
2026
2027
2028
20292030
Rate base
$47.6$50.8$54.4$58.1$62.6$67.9
Rate base using range case discussed above
*$50.8$54.3$57.7$61.7$66.1
*Not applicable
Southern California Wildfires and Mudslides
Unprecedented weather conditions in California due to climate change and greater concentrations of residents in high-fire risk areas, among other things, have contributed to wildfires, including those where SCE's equipment has been alleged to be associated with the fire's ignition, that have caused loss of life and substantial damage in SCE's service area.
SCE continues to implement its WMP to reduce the risk of SCE equipment contributing to the ignition of wildfires. Further to the investments SCE is making as part of its WMP, SCE also uses its PSPS program to proactively de-energize power lines as a last resort to mitigate the risk of significant wildfires during extreme weather events. In addition, California has increased its investment in wildfire prevention and fire suppression capabilities. Yet, the potential for catastrophic wildfire activity in SCE's service area still exists.
In 2025, a Continuation Account within the Wildfire Fund was established under SB 254 to supplement the Initial Account within the Wildfire Fund that was established in 2019. In recognition of the need for further action, SB 254 requires the administrator of the Wildfire Fund to submit to the California legislature and the governor, by April 1, 2026, a report that evaluates and sets forth recommendations on new models or approaches that mitigate damage, accelerate recovery, and responsibly and equitably allocate the burdens from natural catastrophes, including wildfires, across stakeholders, to complement or replace the Wildfire Fund. While Edison International and SCE continue to pursue legislative strategies to address California investor-owned utilities' exposure to wildfire-related liabilities, they cannot predict whether or when there will be a comprehensive economy-wide solution mitigating the significant risk faced by California investor-owned utilities related to wildfires.
Eaton Fire
In January 2025, several wind-driven wildfires impacted portions of SCE's service area, causing loss of life, substantial damage to both residential and business properties, and service outages for SCE customers. One of the largest of these wildfires, the Eaton Fire, ignited in SCE's service area in Los Angeles County and spread due to a number of contributing factors under conditions of an extreme Santa Ana windstorm.
The Los Angeles County Fire Department is leading the investigation into the origin and cause of the Eaton Fire, with the assistance of CAL FIRE, and has identified a preliminary area of origin of the fire. SCE has transmission facilities in the preliminary area of origin and the SED is conducting an investigation with respect to the Eaton Fire. Edison International and SCE are also aware of an ongoing investigation by the Los Angeles District Attorney's Office of the Eaton Fire for the purpose of determining whether any criminal violations have occurred. SCE could be subject to material fines, penalties, or restitution if it is determined that it failed to comply with applicable laws and regulations. SCE is not aware of any basis for
8
Table of Contents
felony liability with regards to the Eaton Fire. Any fines and penalties incurred in connection with the Eaton Fire will not be recoverable from insurance, from the Wildfire Fund, or through electric rates.
Multiple lawsuits related to the Eaton Fire have been initiated against SCE and Edison International by individual plaintiffs, subrogation plaintiffs, and public entity plaintiffs related to the Eaton Fire. A bellwether jury trial in the Eaton Fire litigation has been set for January 2027.
SCE’s internal review into the facts and circumstances of the Eaton Fire is complex and ongoing. SCE's review includes ongoing inspections of its facilities and records and of third-party information and testing. While SCE has not conclusively determined that its equipment caused the ignition of the Eaton Fire, a viable explanation is that a de-energized idle SCE transmission facility in the preliminary area of origin was associated with the ignition of the fire and SCE is not aware of evidence pointing to another possible source of ignition. Absent additional evidence, SCE believes that it is likely that its equipment could have been associated with the ignition of the Eaton Fire and is pursuing settlement of claims through its Wildfire Recovery Compensation Program, a program designed to enable eligible individuals and businesses impacted by the Eaton Fire to seek expedited resolution of their claims.
SCE has entered into settlements with insurance claimants and claimants under its Wildfire Recovery Compensation Program related to the Eaton Fire. As of December 31, 2025, SCE had recorded $1.1 billion in losses related to these settlements. SCE also recorded expected recoveries from customer-funded self-insurance of $917 million, from the Wildfire Fund of $134 million, and through FERC electric rates of $70 million. The net after tax charge to earnings recorded related to the settlements is $9 million, the after-tax impact of the required $12.5 million shareholder contribution related to SCE's customer-funded self-insurance coverage.
In light of pending litigation, it is probable that Edison International and SCE will incur additional material losses in connection with the Eaton Fire. Given, among other things, the complexities associated with estimating damages, the large number and varying types of claims and the interrelationship among the claims, uncertainties related to the sufficiency of insurance held by plaintiffs and potential plaintiffs, and uncertainties related to litigation processes and the Wildfire Recovery Compensation Program, Edison International and SCE are currently unable to reasonably estimate a range of losses that may be incurred in connection with the Eaton Fire.
In January 2026, SCE filed a cross-complaint against certain public and private entities whose actions or inaction may have caused, contributed to or exacerbated the losses that resulted from the fire.
SCE will exhaust self-insurance recoveries available for losses related to the Eaton Fire as a result of costs incurred and settlements entered into as of February 11, 2026. SCE has advised the administrator of the Wildfire Fund that it anticipates that it will seek reimbursement of eligible claims arising from the Eaton Fire from the Initial Account and the administrator has confirmed that the Eaton Fire is a "covered wildfire" for purposes of accessing the Initial Account. SCE will be reimbursed for losses incurred in excess of $1.0 billion for eligible claims for third-party damages related to the Eaton Fire from the Initial Account, subject to approval of the fund administrator and the Initial Account's claims-paying capacity. The fund administrator has reported that the fund's claims-paying capacity for the Eaton Fire, as of September 30, 2025, exceeds $21 billion.
SCE will file an application with the CPUC for review of its costs and expenses related to the Eaton Fire after it has resolved all or, if authorized by the CPUC, substantially all third-party damage claims related to the fire, or upon earlier request of the fund administrator. Because SCE held a valid safety certification at the time of the Eaton Fire, SCE will be presumed to have acted prudently unless a party in the proceeding creates "serious doubt" as to the reasonableness of its conduct, in which case SCE will have the burden of dispelling that doubt and proving its conduct was prudent. The prudency standard does not necessitate perfect conduct and California Wildfire Legislation requires that the CPUC allow recovery if it determines that SCE's conduct related to the ignition of the Eaton Fire was consistent with actions of a reasonable utility. SCE believes that the CPUC's determination regarding the reasonableness of its ignition-related conduct should be based on an evaluation of the reasonableness of its overall policies, systems, and practices. The CPUC has not applied the California Wildfire Legislation prudency framework to a wildfire cost-recovery proceeding.
SCE believes that it is a reasonable operator of its electric system. Based on the information it has reviewed, SCE believes that it will be able to make a good faith showing that its conduct with respect to its transmission facilities in the preliminary area of origin was consistent with the actions of a reasonable utility.
The CPUC will determine the prudency of SCE's ignition-related conduct in a formal proceeding. If the CPUC finds that SCE's conduct related to the ignition of the Eaton Fire was not prudent, it may nevertheless allow cost recovery in full or in part taking into account factors both within and beyond SCE's control that may have exacerbated the costs, including, for example, winds, humidity, temperature, emergency response, evacuation timing and availability of firefighting resources. Because SCE held a safety certification at the time of the ignition, it will be required to reimburse the Initial Account only for amounts disallowed by the CPUC up to the applicable Liability Cap of approximately $4.3 billion, unless the fund
9
Table of Contents
administrator finds that SCE's actions or inactions relative to the ignition of the Eaton Fire constitute conscious or willful disregard of the rights and safety of others, in which case SCE will be required to reimburse the Initial Account for all withdrawn amounts that the CPUC disallowed.
SCE will be able to seek recovery of prudently incurred uninsured wildfire costs not covered by the Initial Account, assessed under the prudency standard clarified under the California Wildfire Legislation, through electric rates.
2017/2018 Wildfire/Mudslide Events
Overview
Multiple lawsuits and investigations related to the 2017/2018 Wildfire/Mudslide Events have been initiated against SCE and Edison International. SCE has previously entered into settlements with a number of local public entities, subrogation and individual plaintiffs in the TKM and Woolsey Fire litigations and under the SED Agreement. As of February 11, 2026, in addition to the outstanding claims of approximately 100 of the approximately 15,000 initial individual plaintiffs, there were alleged and potential claims of certain public entity plaintiffs, including CAL OES, outstanding.
Through December 31, 2025, SCE has recorded estimated losses of $9.9 billion, recoveries from insurance of $2.0 billion, all of which have been collected, and expected recoveries through electric rates of $3.4 billion, $413 million of which has been collected through FERC rates subject to refund, related to the 2017/2018 Wildfire/Mudslide Events claims. The cumulative after-tax net charges to earnings recorded through December 31, 2025, have been $3.2 billion.
As of December 31, 2025, SCE had paid $9.7 billion under executed settlements and had $48 million to be paid under executed settlements, including $42 million to be paid under the SED Agreement, related to the 2017/2018 Wildfire/Mudslide Events. After giving effect to all payment obligations under settlements entered into through December 31, 2025, Edison International's and SCE's best estimate of expected losses for remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events was $144 million.
Estimated losses for the 2017/2018 Wildfire/Mudslide Events litigation are based on a number of assumptions and are subject to change as additional information becomes available. Actual losses incurred may be higher or lower than estimated based on several factors, including the uncertainty in estimating damages that have been or may be alleged. Edison International and SCE may incur a material loss in excess of amounts accrued in connection with the remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events.
Approval of CPUC-Jurisdictional Rate Recovery in 2025
In 2025, SCE recorded regulatory assets for recoveries permitted under the TKM Settlement Agreement and Woolsey Settlement Agreement. Under the TKM Settlement Agreement and the Woolsey Settlement Agreement, SCE is allowed to permanently exclude any after-tax charges to equity associated with the costs disallowed, waived, or funded by shareholders in the settlement agreements and the debt issued to finance those costs from its CPUC regulatory capital structure.
TKM Settlement Agreement
In January 2025, the CPUC approved the TKM Settlement Agreement under which SCE is authorized to recover 60%, or approximately $1.6 billion, of approximately $2.7 billion of losses, consisting of approximately $1.3 billion of uninsured claims paid as of May 31, 2024 and $0.3 billion of associated costs, composed of legal and financing costs incurred as of May 31, 2024 and estimated ongoing financing costs. SCE is also authorized to recover 60% of claims paid and related costs incurred after May 31, 2024, other than for $125 million of uninsured claims and related financing costs which SCE waived its right to seek recovery of under the SED Agreement. In August 2025, the CPUC authorized SCE to finance these amounts through the issuance of securitized bonds and, in December 2025, SCE issued securitized bonds in the amount of $1.6 billion to finance cost recoveries authorized under the TKM Settlement Agreement.
Under the TKM Settlement Agreement, SCE is also authorized to recover approximately $55 million of approximately $65 million in restoration costs incurred. Further, as required under the TKM Settlement Agreement, SCE recorded $50 million of shareholder-funded wildfire mitigation expenses in 2025.
Woolsey Settlement Agreement
In December 2025, the CPUC approved the Woolsey Settlement Agreement. As a result, SCE recorded cost recoveries through CPUC electric rates of approximately $2.0 billion, of approximately $5.6 billion of losses, consisting of approximately $1.6 billion of uninsured claims paid as of May 31, 2025, and $0.4 billion of costs, composed of legal costs paid as of May 31, 2025, and estimated ongoing financing costs. SCE was also authorized to recover 35% of claims paid and related costs incurred after May 31, 2025. SCE’s requests for recovery excluded $250 million of uninsured claims and related financing costs which SCE waived its right to seek recovery of under the SED Agreement. In January 2026, SCE
10
Table of Contents
filed an application to seek approval from the CPUC to finance the amounts authorized under the Woolsey Settlement Agreement through the issuance of securitized bonds. The parties to the Woolsey Settlement Agreement agreed that if SCE’s anticipated application for securitization is denied, the authorized amounts will be recovered in rates over five years, financed using long-term debt.
Under the Woolsey Settlement Agreement, SCE is also authorized to recover approximately $71 million of approximately $84 million in restoration costs incurred. In the Woolsey Settlement Agreement, SCE also waived its right to seek recovery of uninsured losses tracked in a Wildfire Expense Memorandum Account and incurred in connection with fires that ignited prior to July 12, 2019, the date AB 1054 was adopted. SCE estimates that the waived pre-AB 1054 losses are approximately $157 million.
Other Wildfire Events
In addition to the 2017/2018 Wildfire/Mudslide Events, several other wildfires significantly impacted portions of SCE's service area prior to 2025, including the 2017 Creek Fire, the 2019 Saddle Ridge Fire, the 2020 Bobcat Fire, the 2020 Silverado Fire, the 2022 Coastal Fire and the 2022 Fairview Fire.
Through December 31, 2025, SCE has recorded total estimated losses of $1.2 billion, expected recoveries from insurance and third parties of $800 million and expected recoveries through electric rates of $130 million related to the Other Wildfire Events claims. The cumulative after-tax net charges to earnings recorded through December 31, 2025, have been $165 million.
As of December 31, 2025, SCE had paid $943 million under executed settlements and had $4 million to be paid under executed settlements related to the Other Wildfire Events and Edison International's and SCE's estimated losses for remaining alleged and potential claims (established at the low end of the estimated range of reasonably possible losses) related to the Other Wildfire Events was $213 million. As of the same date, SCE had assets for expected recoveries through insurance and third parties of $237 million and through electric rates of $116 million on its consolidated balance sheets related to the Other Wildfire Events.
Edison International and SCE may incur material losses in excess of the amounts accrued for certain of the Other Wildfire Events. Edison International and SCE expect that additional losses incurred in connection with any such fire will be covered by insurance, subject to self-insured retentions and co-insurance, and expect that any such additional losses after expected recoveries from insurance, and third parties, and through electric rates will not be material.
In light of the prudency standard the CPUC is required to apply under California Wildfire Legislation to utilities holding a safety certification at the time a wildfire ignited after July 12, 2019, SCE has concluded, at this time, that both uninsured CPUC-jurisdictional and uninsured FERC-jurisdictional wildfire-related costs related to the Other Wildfire Events that ignited after July 2019 for which it has deferred as regulatory assets are probable of recovery through electric rates. SCE will continue to evaluate the probability of recovery based on available evidence, including regulatory decisions, such as any CPUC decisions illustrating the interpretation and/or application of the prudency standard under California Wildfire Legislation, and, for each applicable fire, evidence that could cast serious doubt as to the reasonableness of SCE's conduct relative to that fire.
For further information on Southern California Wildfires and Mudslides, see "Risk Factors," "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—Wildfire Fund," "Business—Southern California Wildfires" and "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides" in this report.
RESULTS OF OPERATIONS
SCE
The following discusses SCE's consolidated statements of income for 2025 and 2024. In general, expenses SCE is authorized to pass through directly to customers (such as purchased power and fuel expenses, flow-through taxes, as well as costs incurred for various programs and activities, such as public purpose programs and vegetation management activities) and the corresponding amount of revenues collected to recover those pass-through costs do not impact net income.
Impact of 2025 GRC
The 2025 GRC final decision was approved by the CPUC in September 2025, and determines the amount of revenue that SCE is authorized to collect from customers to recover anticipated costs, including return on rate base. The final decision approved an authorized revenue requirement of $9.7 billion in 2025, an increase of $880 million over the adjusted 2024 authorized revenue requirement (see table below for more details).
11
Table of Contents
The table below sets out the authorized revenue and costs of service for the 2024 authorized revenue requirement and the 2025 GRC final decision:
(in millions)2024
Authorized
Revenue
Adjustments1
Adjusted
2024
Authorized
Revenue
2025
Final Decision
Authorized
Revenue2
Increase
Authorized revenue$8,582 $198 $8,780 $9,660 $880 
Cost of service:
Operation and maintenance2,734 — 2,734 2,857 123 
3
Depreciation2,284 108 2,392 2,729 337 
4
Property and payroll taxes487 6 493 550 57 
Income taxes403 25 428 554 126 
Authorized return2,674 59 2,733 2,970 237 
5
Total$8,582 $198 $8,780 $9,660 $880 
1Adjustments to the 2024 authorized revenue requirement primarily related to the Customer Service Re-Platform project, which was recovered through a CPUC non-GRC recovery mechanism and approved to be included in the GRC-authorized revenue in the 2025 GRC.
2Reflects SCE's GRC authorized revenue as filed in SCE's September 2025 GRC implementation advice letter.
3Authorized revenue for operation and maintenance expenses increased primarily due to higher authorized wildfire expenditures.
4Authorized revenue for depreciation increased primarily due to higher plant balances.
5Authorized revenue for return increased primarily due to authorized rate base growth.
SCE recorded net charges of $76 million ($39 million after-tax), primarily due to an $88 million impairment of utility property, plant and equipment associated with historical capital expenditures disallowed in the final decision, mainly related to the rooftop solar photovoltaic program. This was partially offset by the recognition of a $12 million clean energy subsidy previously received for this program.
12
Table of Contents
Years ended December 31, 2025 and 2024
The following table is a summary of SCE's results of operations for the periods indicated:
Years ended December 31,Favorable (Unfavorable)
(in millions)202520242025 to 2024
Operating revenue$19,276 $17,547 $1,729 
Purchased power and fuel4,933 5,209 276 
Operation and maintenance4,999 5,064 65 
Wildfire-related claims, net of (recoveries)(2,009)647 2,656 
Wildfire Fund expense144 146 2 
Depreciation and amortization3,233 2,865 (368)
Property and other taxes662 620 (42)
Asset impairment106 — (106)
Total operating expenses12,068 14,551 2,483 
Operating income7,208 2,996 4,212 
Interest expense(1,207)(1,575)368 
Other income, net447 493 (46)
Income before income taxes6,448 1,914 4,534 
Income tax expense1,415 120 (1,295)
Net income5,033 1,794 3,239 
Less: Preference stock dividend requirements144 175 31 
Net income available for common stock$4,889 $1,619 $3,270 
2025 vs 2024
Operating Revenue
Higher net operating revenue of $1,729 million was primarily due to:
•An increase in revenue of $880 million resulting from implementing the 2025 GRC final decision, as discussed in "—Impact of 2025 GRC."
•An increase in revenue of $758 million related to net higher expenses that are passed through to customers, which included increases in:
•Wildfire-related claims of $899 million;
•Depreciation and amortization expense of $108 million;
•Interest expense of $38 million;
•Property and other taxes of $11 million;
•Other income of $4 million;
•Income tax expense of $2 million;
partially offset by decreases in:
•Purchased power and fuel expense of $276 million;
•Operation and maintenance expense of $28 million.
•An increase in revenue of $91 million was primarily due to higher balancing account rate base primarily associated with wildfire mitigation efforts and utility owned energy storage projects.
13
Table of Contents
Purchased Power and Fuel
A decrease in purchased power and fuel costs of $276 million was primarily due to lower power prices (offset in "Operating Revenue" above).
Operation and Maintenance
A decrease in operation and maintenance expense of $65 million was primarily due to:
•A net decrease of $28 million related to lower expenses that are passed through to customers (offset in "Operating Revenue" above, which mainly included:
•A net lower expense of $273 million related to previously deferred wildfire mitigation, vegetation management, and emergency restoration costs authorized for recovery in 2025 than in 2024.
These decreases are partially offset by:
•$98 million higher FERC-jurisdictional costs primarily due to increased transmission allocation;
•$78 million higher uncollectible expense;
•$69 million primarily related to higher public programs expenses.
•A decrease of $115 million in legal costs, of which $58 million related to recoveries under the TKM Settlement Agreement, $37 million related to recoveries under the Woolsey Settlement Agreement, and $20 million related to lower costs associated with the 2017/2018 Wildfire/Mudslide Events. See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
•A decrease of $53 million related to severance costs recorded in 2024 due to workforce reductions.
•A charge of $62 million recorded in 2025 primarily associated with disallowed historical expenses related to 2021 GRC wildfire mitigation memorandum account balances. For additional information, see "Liquidity and Capital Resources—SCE—Regulatory Proceedings."
•A charge of $50 million recorded in 2025 related to shareholder-funded wildfire mitigation costs stipulated under the TKM Settlement Agreement. See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
•An increase of $19 million primarily related to higher wildfire mitigation related activities.
Wildfire-related Claims, Net of Recoveries
A decrease in wildfire-related claims, net of recoveries of $2,656 million was primarily due to:
•A recovery of $1,603 million in claim costs was recorded in 2025 as authorized under the Woolsey Settlement Agreement.
•A recovery of $1,341 million in claim costs was recorded in 2025 as authorized under the TKM Settlement Agreement.
•A decrease of $490 million related to lower claim costs for 2017/2018 Wildfire/Mudslide Events recorded in 2025 than in 2024, $28 million of which was expected to be recovered through FERC rates (offset in "Operating Revenue" above).
•A decrease of $157 million related to lower claim costs recorded in 2025 than in 2024 for Other Wildfire Events, $10 million of which was expected to be recovered through FERC rates (offset in "Operating Revenue" above).
•A decrease of $14 million due to insurance reimbursements recorded in 2025 for costs incurred in previous years related to Other Wildfire Events.
partially offset by:
•An increase of $949 million related to wildfire claim costs recorded in 2025 related to the Eaton Fire. These costs include $917 million covered by customer-funded self-insurance and $19 million expected FERC recovery (offset in "Operating Revenue" above) and $12.5 million from the shareholder contribution related to SCE's customer-funded self-insurance coverage.
14
Table of Contents
For further information, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
Depreciation and Amortization
An increase in depreciation and amortization expense of $368 million was primarily due to higher plant balances, $108 million of which were pass-through costs mainly associated with wildfire mitigation costs and utility owned energy storage projects (offset in "Operating Revenue" above).
Property and Other Taxes
An increase in property and other taxes expense of $42 million was primarily due to higher assessed property values, $11 million of which were pass-through costs mainly associated with wildfire mitigation costs and utility owned energy storage projects (offset in "Operating Revenue" above).
Asset Impairment
Charges of $106 million recorded in 2025 primarily related to:
•$88 million impairment of utility property, plant and equipment associated with historical capital expenditures disallowed in SCE's 2025 GRC final decision.
•$18 million impairment of utility property, plant and equipment associated with historical capital expenditures disallowed in the TKM and Woolsey Settlement Agreements.
Interest Expense
A net decrease in interest expense of $368 million was primarily due to:
•$171 million benefit related to cost recoveries authorized under the TKM Settlement Agreement;
•$243 million benefit related to cost recoveries under the Woolsey Settlement Agreement;
partially offset by:
•$38 million pass-through expense mainly associated with wildfire mitigation efforts and utility owned energy storage projects (offset in "Operating Revenue" above);
•$8 million higher interest expense from higher borrowings.
Other Income, Net
A decrease in other income, net of $46 million was primarily due to lower interest income driven by lower balancing account undercollection balances, and $4 million of higher pass-through costs (offset in "Operating Revenue" above).
Income Tax Expense
An increase in income tax expense of $1,295 million was primarily due to higher tax expense on higher pre-tax income. See "Notes to Consolidated Financial Statements—Note 8. Income Taxes" for a reconciliation of the federal statutory rate to the effective income tax rate.
Preference Stock Dividend Requirements
A decrease in preference stock dividend requirements of $31 million was primarily due to a lower amount of outstanding preference stock following 2024 and 2025 redemptions.
Edison International Parent and Other
Results of operations for Edison International Parent and Other include amounts from other subsidiaries that are not reportable segments, as well as intercompany eliminations.
15
Table of Contents
Loss from Operations
The following table summarizes the results of Edison International Parent and Other:
Years ended December 31, Favorable (Unfavorable)
(in millions)202520242025 to 2024
Edison International Parent and Other net loss$(332)$(248)$(84)
Less: Preferred stock dividend requirements98 87 (11)
Edison International Parent and Other net loss available to common shareholders$(430)$(335)$(95)
The net loss available to common shareholders from operations of Edison International Parent and Other increased $95 million in 2025 compared to 2024 primarily due to expenses from wildfire claims insured by an EIS insurance contract (see "Notes to Consolidated Financial Statements— Note 12. Commitments and Contingencies and Note 17. Related-Party Transactions" for further information), higher interest expense, and preferred stock redemption loss in 2025.
LIQUIDITY AND CAPITAL RESOURCES
SCE
SCE's ability to operate its business, fund capital expenditures, and implement its business strategy is dependent upon its operating cash flow and access to the bank and capital markets. SCE's overall cash flows fluctuate based on, among other things, its ability to recover its costs in a timely manner from its customers through regulated rates, changes in commodity prices and volumes, collateral requirements, interest obligations, dividend payments to and equity contributions from Edison International, obligations to preference shareholders, and the outcome of tax, regulatory and legal matters.
In the next 12 months, SCE expects to fund its cash requirements through operating cash flows, capital market and bank financings, and equity contributions from Edison International Parent, as needed. In addition, SCE expects to fund authorized wildfire-related cost recoveries through securitization financings, and fund costs related to the Eaton Fire through customer-funded self-insurances and reimbursement from the Initial Account. SCE also has availability under its credit facility and agreements with lenders to issue bilateral unsecured standby letters of credit to fund cash requirements. SCE may issue additional debt for general corporate purposes.
In December 2025, SCE issued securitized bonds in the amount of $1.6 billion to finance cost recoveries authorized under the TKM Settlement Agreement. In addition, SCE expects to finance approximately $2.0 billion of cost recoveries authorized under the Woolsey Settlement Agreement by issuing securitized bonds, subject to the approval of a securitization financing application filed in January 2026. For further details on the settlements, see "Management Overview—Southern California Wildfires and Mudslides."
During the year ended December 31, 2025, SCE issued a total of $3.0 billion of first and refunding mortgage bonds. In February 2026, SCE entered into a term loan agreement to borrow up to $300 million due in March 2027. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
In December 2025, SCE repurchased 7,250,967 shares of 5.45% Fixed-to-Floating Rate Trust Preference Securities (the "Series K Trust Securities") issued by SCE Trust V through a tender offer for an aggregate amount paid of $181 million, which includes accrued and unpaid dividends. SCE subsequently exchanged substantially all of these Series K Trust Securities for 72,509 shares of SCE's Series K preference stock, which it retired. SCE paid the consideration and the fees and expenses incurred with cash on hand. In addition, in December 2025, SCE fully redeemed 5.375% Fixed-to-Floating Rate Trust Preference Securities (the "Series J Trust Securities") issued by SCE Trust IV for an aggregate amount paid of $325 million. SCE subsequently exchanged all of these Series J Trust Securities for SCE's Series J preference stock, which it retired. In February 2026, SCE announced that it will redeem all the outstanding shares of its Series K preference stock which will cause SCE Trust V to redeem all of its outstanding 5.45% Series K Trust Securities. The redemption date will be March 15, 2026 at the redemption price of $25 per Series K Trust Security. For further details, see "Notes to Consolidated Financial Statements—Note 14. Equity."
For restrictions on SCE's ability to pay dividends, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends."
Credit Ratings
Following the passage of SB 254 in September 2025, Moody's reaffirmed SCE's long-term issuer credit rating and outlook, and Fitch also reaffirmed SCE's credit rating and revised its outlook from ratings watch negative to stable. However, S&P
16
Table of Contents
downgraded SCE's long-term issuer credit rating. For further details on SB 254, see "Business—Southern California Wildfires—Recovery of Wildfire-Related Costs—California Wildfire Legislation." The following table summarizes SCE's current long-term issuer credit ratings and outlook from the major credit rating agencies as of February 11, 2026:
Moody'sFitchS&P
Credit RatingBaa1BBBBBB-
OutlookStableStableNegative
SCE's credit ratings may be affected by various factors. These include, but are not limited to, failure by regulators to successfully implement the California Wildfire Legislation in a consistent and credit supportive manner, or investigations into wildfire events or associated settlements result in material utility liability exposure, particularly in the absence of broader credit-supportive legislative actions to mitigate SCE's wildfire risk, including those to be recommended under SB 254 in a report due April 1, 2026. Additionally, a persistent increase in the frequency and severity of wildfires in California may lead the credit rating agencies to reassess SCE's wildfire-related operational risk exposure or believe the Wildfire Fund is at risk of material depletion. Credit rating downgrades increase the cost and may impact the availability of short-term and long-term borrowings, including commercial paper, credit facilities, bond financings or other borrowings. In addition, some of SCE's power procurement contracts, environmental remediation obligations and workers' compensation self-insurance would require SCE to pay related liabilities or post additional collateral if SCE's credit rating were to fall below investment grade. For further details, see "—Margin and Collateral Deposits."
Available Liquidity
At December 31, 2025, SCE had cash on hand of $98 million and restricted cash of $522 million collected from customer-funded self-insurance. SCE also has approximately $2.3 billion available to borrow on its $3.4 billion revolving credit facility. The credit facility is available for borrowing needs until May 2029. The aggregate maximum principal amount under the SCE revolving credit facility may be increased up to $4.0 billion, provided that additional lender commitments are obtained. SCE also had standby letters of credit with total capacity of $660 million, and the unused amount was $513 million as of December 31, 2025. At December 31, 2025, SCE had $1.0 billion outstanding commercial paper, net of discount, at a weighted average interest rate of 4.59% supported by the revolving credit facility. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
SCE may finance balancing account undercollections and working capital requirements to support operations and capital expenditures with commercial paper, its credit facilities or other borrowings, subject to availability in the bank and capital markets and within levels authorized by the CPUC. As necessary, SCE will utilize its available liquidity, capital market financings, other borrowings or parent company equity contributions to SCE in order to meet its obligations as they become due, including costs related to the wildfire events. SCE expects to use customer-funded self-insurance and reimbursement from the Initial Account to fund wildfire claims. For further information, see "Management Overview—Southern California Wildfires and Mudslides."
Debt Covenant
SCE's credit facilities and term loan require a debt to total capitalization ratio as defined in the applicable agreements of less than or equal to 0.65 to 1. At December 31, 2025, SCE's debt to total capitalization ratio was 0.57 to 1.
At December 31, 2025, SCE was in compliance with all financial covenants that affect access to capital.
Regulatory Proceedings
Wildfire Related Regulatory Proceedings
In response to the increase in wildfire activity and faster progression of and increase in damage from wildfires across SCE's service area and throughout California, SCE has incurred wildfire mitigation and wildfire and drought restoration related spending at levels exceeding amounts authorized in SCE's GRCs. For regulatory proceedings related to the 2017/2018 Wildfire/Mudslide Events, see "Management Overview—Southern California Wildfires and Mudslides."
2024 Multi-year Wildfire Mitigation and Catastrophic Events Filing ("2024 WMCE Filing")
In December 2025, SCE filed its 2024 WMCE Filing, seeking to recover incremental operating and maintenance expenses of $55 million and incremental capital expenditures of $78 million, recorded in the wildfire risk mitigation balancing account, as well as incremental storm-related costs associated with certain 2017 – 2021 events recorded in the catastrophic event memorandum account. The application also seeks recovery of $36 million in wildfire mitigation related capital expenditures incurred in 2022 that were previously denied without prejudice and permitted to be included in base rates as
17
Table of Contents
part of the post-test year ratemaking mechanism, see "—2021 GRC Wildfire Mitigation Memorandum Account Balances" for further discussion. SCE proposed a procedural schedule with the final decision in December 2026.
2023 Multi-year Wildfire Mitigation and Catastrophic Events Filing ("2023 WMCE Filing")
In June 2025, the CPUC approved a settlement agreement among SCE, Cal Advocates, and Small Business Utility Advocates in the WMCE proceeding under which SCE is authorized to recover $702 million in capital expenditures and $308 million in operation and maintenance expenses. This resulted in an initial revenue requirement of $314 million, which has been implemented into customer rates over a 12-month period starting October 1, 2025, along with ongoing capital revenue requirement and interest.
2021 GRC Wildfire Mitigation Memorandum Account Balances
In June 2025, the CPUC issued a final decision that authorized recovery of $291 million in operations and maintenance expenses and $99 million in capital expenditures. The portion of the initial revenue requirement above the interim rate recovery levels has been implemented in customer rates over a 12-month period starting October 1, 2025, along with ongoing capital revenue requirement and interest. Additionally, the final decision disallowed recovery of $65 million in operations and maintenance expenses, and determined that $36 million of requested capital expenditures were not eligible for recovery as part of this proceeding. SCE has filed an application for rehearing with the CPUC regarding the disallowances in this decision.
NextGen Enterprise Resource Planning ("ERP") Program
In March 2025, SCE filed an application with the CPUC seeking funding for the replacement of its core ERP system that has been in service for over 15 years and will soon reach the end of its service life. SCE requested funding through a balancing account of recorded and forecast capital expenditures of approximately $1.1 billion and operations and maintenance expenditures of $239 million. SCE anticipates a proposed decision will be issued by the CPUC in 2026.
2026 FERC Formula Rate Annual Update
In November 2025, SCE filed its 2026 annual transmission revenue requirement update with the FERC, with rates effective January 1, 2026. The update reflects a 2026 transmission revenue requirement of $1.5 billion, which is a $157 million, or 12%, increase from the 2025 annual rates. The increase is primarily due to 2026 rates reflecting recovery of previous undercollections.
Capital Investment Plan
Major Transmission Projects
A summary of SCE's most significant transmission and substation construction projects is presented below. The timing of the projects below is subject to timely receipt of permitting, licensing, and regulatory approvals.
Project NameProject
Lifecycle Phase
Direct
Expenditures
(in millions)1
Inception to Date
(in millions)1
Scheduled In-
Service Date
Riverside Transmission Reliability2
Construction
748 99 2029
Alberhill System
Licensing464 61 2029
Eldorado-Lugo-Mohave UpgradeConstruction379 326 2025
1Direct expenditures include direct labor, land, and contract costs incurred for the respective projects and exclude overhead costs that are included in the capital expenditures forecast discussed in "Management Overview—Capital Program."
2Direct expenditures were adjusted for inflation with no change to the scope of the project.
Riverside Transmission Reliability Project
The Riverside Transmission Reliability Project is a joint project between SCE and Riverside Public Utilities ("RPU"), the municipal utility department of the City of Riverside. While RPU will be responsible for constructing some of the project's facilities within Riverside, SCE's portion of the project consists of constructing upgrades to its system, including a new 230 kV substation; certain interconnection and telecommunication facilities and overhead transmission lines in the cities of Riverside, Jurupa Valley, and Norco and in portions of unincorporated Riverside County. SCE began construction in June 2025. The current cost estimate of the project is $748 million and the project is expected to be completed in 2029.
18
Table of Contents
Alberhill System Project
The Alberhill System Project consists of constructing a new 500 kV substation, two 500 kV transmission lines to connect the proposed substation to the existing Serrano-Valley 500 kV transmission line, telecommunication equipment, and subtransmission lines in western Riverside County. The project was designed to meet long-term forecasted electrical demand in the proposed Alberhill System Project area and to increase electrical system reliability and resiliency. In June 2024, the CPUC issued an addendum to its 2017 Final Environmental Impact Report, concluding its California Environmental Quality Act review. The project is now seeking final CPUC approval to begin construction. SCE is expecting the final CPUC decision in the first quarter of 2026.
Eldorado-Lugo-Mohave Upgrade Project
The Eldorado-Lugo-Mohave Upgrade Project will increase capacity on existing transmission lines to allow additional renewable energy to flow from Nevada to Southern California. The project would modify SCE's existing Eldorado, Lugo, and Mohave electrical substations to accommodate the increased power flows from Nevada to southern California; increase the power flow through the existing 500 kV transmission lines by constructing two new capacitors along the lines; raise transmission tower heights to meet ground clearance requirements; and install fiber optics on the transmission lines to provide communications between existing SCE substations. In August 2020, the CPUC approved the certificate of public convenience and necessity ("CPCN") for the project.
Construction for the project began in November 2020. The total costs for the Eldorado-Lugo-Mohave Upgrade Project are expected to exceed amounts currently approved in the CPCN granted by the CPUC due to delays in regulatory approvals, contractor performance issues, supply chain constraints, COVID-19 impacts, and the availability of CAISO outage windows. SCE's petition for modification ("PFM") to increase the direct expenditures for the project from $247 million to $319 million was approved by CPUC and the project went into service in 2025. Additional work after the in-service date is required to mitigate the impact of the project on nearby natural gas transmission lines. In January 2026, SCE filed a second PFM to request an approximately $48 million to address the additional costs of the mitigation work. The mitigation work is expected to be completed in 2026.
Decommissioning of San Onofre
The decommissioning of a nuclear plant requires the management of three related activities: radiological decommissioning, non-radiological decommissioning, and the management of spent nuclear fuel. SCE is the operating agent of San Onofre and engaged the DGC to undertake a significant scope of decommissioning activities for the three nuclear reactor installations at San Onofre: Units 1, 2 and 3. The decommissioning of San Onofre is expected to take many years. SCE funds decommissioning costs, including costs associated with storing spent nuclear fuel, with assets that are currently held in nuclear decommissioning trusts.
Under federal law, the U.S. Department of Energy ("DOE") is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. The DOE has not met its contractual obligation to accept spent nuclear fuel. Extended delays by the DOE have led to the construction of costly alternatives and associated siting and environmental issues. Two Independent Spent Fuel Storage Installations ("ISFSI") store nuclear fuel onsite at San Onofre. The first stores nuclear fuel from all three Units ("ISFSI 1") and the second stores nuclear fuel from Units 2 and 3 ("ISFSI 2").
SCE's two Coastal Development Permits ("CDPs"), the principal discretionary permits required for maintaining the ISFSIs onsite, currently extend through 2035. SCE must apply to amend the CDPs before the permits expire, proposing whether to retain, remove, or relocate the ISFSI.
Decommissioning of Unit 1 began in 1999 and the transfer of spent nuclear fuel from Unit 1 to dry cask storage in ISFSI 1 was completed in 2005. Major decommissioning work for Unit 1 has been completed except for certain underground work.
Decommissioning of Units 2 and 3 began in June 2013 and the transfer of spent nuclear fuel from Units 2 and 3 to dry cask storage in the two ISFSIs was completed in August 2020. In August 2020, SCE commenced, and is currently conducting, major decommissioning activities in accordance with the terms of the CDP for decommissioning Units 2 and 3.
SCE's share of the Units 2 and 3 decommissioning costs recorded for the years ended December 31, 2025 and 2024 were $163 million (in 2025 dollars) and $218 million (in 2024 dollars), respectively. The CPUC conducts a reasonableness review of recorded decommissioning costs in NDCTPs, which are submitted every three years.
SCE filed its 2024 NDCTP in December 2024. In the 2024 NDCTP, SCE requests reasonableness review of approximately $538 million (SCE share in 2024 dollars) of recorded Units 2 and 3 decommissioning costs incurred during the period 2021 to 2023. SCE also requests approval of an updated decommissioning cost estimate for decommissioning activities to be completed at Units 2 and 3 of $3.0 billion, of which $2.3 billion is SCE's share (in 2024 dollars). The decommissioning
19
Table of Contents
cost estimate includes costs through the expected decommissioning completion date, currently estimated to be in 2056. SCE anticipates a proposed decision will be issued by the CPUC in 2026.
Decommissioning cost estimates are subject to a number of uncertainties including the cost and timing of nuclear waste disposal, the time it will take to obtain required permits, cost of removal of property, site remediation costs, as well as a number of other assumptions and estimates, including when the federal government will provide for either interim or permanent off-site storage of spent nuclear fuel enabling the removal and transport of spent fuel canisters from the San Onofre site, as to which there can be no assurance. Cost estimates are subject to change as decommissioning proceeds and such changes may be material.
SCE had nuclear decommissioning trust funds for Units 2 and 3 of $2.0 billion at December 31, 2025 and $2.1 billion at December 31, 2024. Based upon the resolution of a number of uncertainties, including the uncertainties of decommissioning discussed above, the financial performance of the nuclear decommissioning trust fund investments, as well as the resolution of a number of other assumptions and estimates, additional contributions to the nuclear decommissioning trust's funds may be required. If additional contributions to the nuclear decommissioning trust funds become necessary, SCE will seek recovery of additional contributions to the decommissioning trust through electric rates and any such recovery will be subject to a reasonableness review by the CPUC. Cost increases resulting from contractual disputes, delays in performance by the contractor, elevated levels of inflation, or permitting delays, among other things, could cause SCE to materially overrun the decommissioning cost estimate and could materially impact the sufficiency of trust funds.
In December 2025, the CPUC approved disbursements from SCE's nuclear decommissioning trusts to cover forecasted 2026 decommissioning costs for Units 2 and 3, of which SCE's share is approximately $167 million in 2026 dollars.
Margin and Collateral Deposits
Certain derivative instruments, power and energy procurement contracts, and other contractual arrangements contain collateral requirements. Future collateral requirements may differ from the requirements at December 31, 2025 due to the addition of incremental power and energy procurement contracts with collateral requirements, if any, the impact of changes in wholesale power and natural gas prices on SCE's contractual obligations, and the impact of SCE's credit ratings falling below investment grade. See "—SCE" above for further information on SCE's credit ratings.
The table below provides the amount of collateral posted by SCE to its counterparties as well as the potential collateral that would have been required as of December 31, 2025, if SCE's credit rating had been downgraded to below investment grade as of that date. The table below also provides the potential collateral that could be required due to adverse changes in wholesale power and natural gas prices over the remaining lives of existing power and fuel contracts.
In addition to amounts shown in the table, power and fuel contract counterparties may also institute new collateral requirements, applicable to future transactions to allow SCE to continue trading in power and fuel contracts at the time of a downgrade or upon significant increases in market prices.
(in millions)
Collateral posted as of December 31, 20251
$221
Incremental collateral requirements for purchased power and fuel contracts resulting from a potential downgrade of SCE's credit rating to below investment grade2
10
Incremental collateral requirements for purchased power and fuel contracts resulting from adverse market price movements3
26
Posted and potential collateral requirements$257
1Net collateral provided to counterparties and other brokers consisted of $157 million in letters of credit and surety bonds and $64 million of cash collateral.
2Represents potential collateral requirements for accounts payable and mark-to-market valuation at December 31, 2025. Requirement varies throughout the period and is generally lower at the end of the month.
3Incremental collateral requirements were based on potential changes in SCE's forward positions as of December 31, 2025 due to adverse market price movements over the remaining lives of the existing power and fuel derivative contracts using a 95% confidence level.
Furthermore, SCE may be required to post collateral for workers' compensation in excess of standard formula amounts, currently up to $115 million, in the event of volatile credit rating conditions, during which the Office of Self-Insurance Plans, which oversees workers' compensation self-insurance within California, may exercise discretion to impose higher collateral requirements. SCE posted $12 million under such discretionary authority in the second quarter of 2025. SCE may
20
Table of Contents
also be required to post up to $50 million in collateral in connection with its environmental remediation obligations, within 120 days of the end of the fiscal year in which a downgrade below investment grade occurs.
Edison International Parent and Other
In the next 12 months, Edison International Parent expects to fund its net cash requirements through cash on hand, dividends from SCE, and capital market and bank financings. Edison International Parent may finance its ongoing cash requirements, including dividends, working capital requirements, payment of obligations, and capital investments, including capital contributions to subsidiaries, with short-term or other financings, subject to availability in the bank and capital markets.
At December 31, 2025, Edison International Parent had cash on hand of $60 million and $744 million available to borrow on its $1.5 billion revolving credit facility. The credit facility is available for borrowing needs until May 2029. The aggregate maximum principal amount under the Edison International Parent revolving credit facility may be increased up to $2.0 billion, provided that additional lender commitments are obtained. For further information, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
At December 31, 2025, Edison International Parent had $754 million outstanding commercial paper, net of discount, at a weighted-average interest rate of 4.58% supported by the revolving credit facility.
In the first quarter of 2025, Edison International Parent issued $550 million of senior notes. In December 2025, Edison International Parent borrowed $600 million under a term loan agreement due in December 2026. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
In December 2025, Edison International repurchased 744,975 shares of its Series A Preferred Stock and 415,517 shares of its Series B Preferred Stock through a tender offer for an aggregate amount paid of $1.2 billion, which includes accrued and unpaid dividends. Edison International paid the consideration and the fees and expenses incurred with cash on hand and proceeds of debt issuances. In February 2026, Edison International announced that it will redeem all outstanding shares of its Series A Preferred Stock. The redemption date will be March 9, 2026 at the redemption price of $1,000 per share of Series A Preferred Stock. For further information, see "Notes to Consolidated Financial Statements—Note 14. Equity."
On February 18, 2026, Edison International declared a common stock dividend of $0.8775 per share to be paid on April 30, 2026. Edison International Parent and Other's liquidity and its ability to pay operating expenses and pay dividends to common shareholders are dependent on access to the bank and capital markets, dividends from SCE, realization of tax benefits and its ability to meet California law requirements for the declaration of dividends. Prior to declaring dividends, the Edison International Board of Directors evaluates available information, including when applicable, information pertaining to wildfire events, to ensure that the California law requirements for the declarations are met. For information on the California law requirements on the declaration of dividends, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends." Edison International intends to maintain its target payout ratio of 45% – 55% of SCE's core earnings, subject to the factors identified above.
Edison International's ability to declare and pay common dividends may be restricted under the terms of its Series A and Series B Preferred Stock. For further information, see "Notes to Consolidated Financial Statements—Note 14. Equity."
Edison International Parent's credit facility and term loan requires a consolidated debt to total capitalization ratio as defined in the applicable agreements of less than or equal to 0.70 to 1. At December 31, 2025, Edison International's consolidated debt to total capitalization ratio was 0.64 to 1.
At December 31, 2025, Edison International Parent was in compliance with all financial covenants that affect access to capital.
Credit Ratings
Following the passage of SB 254 in September 2025, Moody's reaffirmed SCE's long-term issuer credit rating and outlook, and Fitch also reaffirmed SCE's credit rating and revised its outlook from ratings watch negative to stable. However, S&P downgraded SCE's long-term issuer credit rating. For further details on SB 254, see "Business—Southern California Wildfires—Recovery of Wildfire-Related Costs—California Wildfire Legislation." The following table summarizes Edison International Parent's current long-term issuer credit ratings and outlook from the major credit rating agencies, and Edison
21
Table of Contents
International Parent's credit rating outlook as of February 11, 2026:
Moody'sFitchS&P
Credit RatingBaa2BBBBBB-
OutlookStableStableNegative
Edison International Parent's credit ratings may be affected by various factors. These include, but are not limited to, failure by regulators to successfully implement the California Wildfire Legislation in a consistent and credit-supportive manner, or investigations into wildfire events or associated settlements result in material utility liability exposure, particularly in the absence of broader credit-supportive legislative actions to mitigate SCE's wildfire risk, including those to be recommended under SB 254 in a report due April 1, 2026. Additionally, a persistent increase in the frequency and severity of wildfires in California may lead the credit rating agencies to reassess Edison International Parent's wildfire-related operational risk exposure or believe the Wildfire Fund is at risk of material depletion. Credit rating downgrades increase the cost and may impact the availability of short-term and long-term borrowings, including commercial paper, credit facilities, note financings or other borrowings.
Edison International Income Taxes
Net Operating Loss and Tax Credit Carryforwards
At December 31, 2025, Edison International has approximately $3.1 billion of tax effected net operating losses and tax credit carryforwards available to offset future consolidated tax liabilities, after excluding $106 million of Capistrano Wind tax attributes and offsetting $404 million of unrecognized tax benefits.
See "Notes to Consolidated Financial Statements—Note 8. Income Taxes" for further information regarding taxes payable to Capistrano Wind.
Inflation Reduction Act of 2022
The IRA imposes a 15% corporate alternative minimum tax ("CAMT") on adjusted financial statement income ("AFSI") of corporations with average AFSI exceeding $1.0 billion over the three preceding calendar years. The CAMT was effective beginning January 1, 2023. Based on the current interpretation of the law and historical financial data, Edison International estimates that it will exceed the $1.0 billion threshold and be subject to CAMT on its consolidated federal tax returns beginning in 2026. SCE will also be subject to CAMT in 2026.
Under the IRA, SCE generated investment tax credits of approximately $231 million in 2024 related to utility owned storage projects and $29 million in nuclear production tax credits. In 2025, SCE monetized the majority of these credits for $236 million. SCE expects to pass the proceeds, net of transaction fees, back to customers.
The One Big Beautiful Bill Act of 2025
On July 4, 2025, the One Big Beautiful Bill Act of 2025 ("OBBBA") was enacted into law. The OBBBA, among other things, phases out various clean energy credits enacted as part of the IRA. These phase-outs, however, are not expected to impact the investment tax credits related to SCE's utility owned storage projects discussed above under "—Inflation Reduction Act of 2022."
Edison International and SCE expect most of the impacts resulting from the implementation of the OBBBA will be passed through to customers.
Historical Cash Flows
SCE
Years ended December 31,Change
(in millions)20252024
2025 vs. 2024
Net cash provided by operating activities$6,152 $5,383 $769
Net cash provided by financing activities269 314 (45)
Net cash used in investing activities(6,329)(5,530)(799)
Net increase in cash, cash equivalents and restricted cash$92 $167 $(75)
22
Table of Contents
Net Cash Provided by Operating Activities
The following table summarizes major categories of net cash provided by operating activities as provided in more detail in SCE's consolidated statements of cash flows for 2025 and 2024:
Years ended December 31,Change
(in millions)202520242025 vs. 2024
Net income$5,033 $1,794 
Non-cash items
4,707 3,013 
Subtotal9,740 4,807 $4,933 
Contributions to Wildfire Fund
(95)(95)— 
Changes in working capital
424 (221)645 
Regulatory assets and liabilities(3,445)1,219 (4,664)
Wildfire related claims, net of insurance recoveries
(607)(319)(288)
Other noncurrent assets and liabilities1
135 (8)143 
Net cash provided by operating activities$6,152 $5,383 $769 
1Includes nuclear decommissioning trusts. See "Nuclear Decommissioning Activities" below for further information. The amount in 2025 includes $236 million in cash proceeds primarily from the monetization of investment tax credits related to utility owned storage projects, which SCE expects to flow through to customers. The amount in 2024 also includes cash received from customers to fund certain construction projects and cash received for a state incentive program to pass through to customers.
Net cash provided by operating activities increased by $769 million in 2025 compared to 2024. The increase was primarily due to $645 million from changes in working capital and the investment tax credit proceeds of $236 million mentioned above in the change of other noncurrent assets and liabilities.
The net inflows (outflows) in cash resulting from working capital were $424 million and $(221) million in 2025 and 2024, respectively. Net cash inflows for 2025 were primarily due to cash collected from the sale of renewable energy credits under a CPUC-established program during 2025 and a decrease in accounts receivable primarily resulted from improved collection. The net cash outflow in 2024 was mainly due to increases in unbilled revenue and power procurement related receivables.
Net cash (used in)/provided by regulatory assets and liabilities, including changes in net over or undercollections recorded in balancing accounts, was $(3,445) million and $1,219 million in 2025 and 2024, respectively. Net decrease in regulatory assets and liabilities of $4.7 billion is primarily due to cost recoveries authorized under the TKM and Woolsey Settlement Agreements, as well as higher revenue from the 2025 GRC final decision, which is mostly offset with the increase in net income after adjustment for non-cash items. In addition, the remaining change in regulatory assets and liabilities is mainly due to a decrease in the recovery of prior year undercollections in 2025 compared to 2024. This decrease is driven by undercollections caused by higher gas prices in 2023, which were collected in 2024.
Net Cash Provided by Financing Activities
The following table summarizes cash provided by financing activities for 2025 and 2024. Issuances of debt are discussed in "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
23
Table of Contents
Years ended December 31,Change
(in millions)20252024
2025 vs. 2024
Long-term debt issued, net of discount and issuance costs
$4,593 $4,214 $379 
Long-term debt repaid(1,252)(2,201)949 
Short-term debt borrowed410 — 410 
Short-term debt repaid(129)(386)257 
Commercial paper financing, net(504)94 (598)
Preference stock issued, net of issuance cost— 345 (345)
Preference stock redeemed(504)(628)124 
Capital contributions from Edison International Parent— 500 (500)
Payment of common stock dividends to Edison International Parent(2,220)(1,440)(780)
Payment of preference stock dividends(136)(168)32 
Other11 (16)27 
Net cash provided by financing activities$269 $314 $(45)
Net Cash Used in Investing Activities
Cash flows used in investing activities are primarily due to capital expenditures and funding of nuclear decommissioning trusts. Cash used in capital expenditures were $6.5 billion and $5.7 billion for 2025 and 2024, respectively, primarily related to transmission, distribution and generation investments. SCE had a net redemption of nuclear decommissioning trust investments of $121 million in both 2025 and 2024. See "Nuclear Decommissioning Activities" below for further discussion.
Nuclear Decommissioning Activities
SCE's consolidated statements of cash flows include nuclear decommissioning activities, which are reflected in the following line items:
Years ended December 31,Change
(in millions)20252024
2025 vs. 2024
Net cash used in operating activities:
Net earnings from nuclear decommissioning trust investments
$53 $40 $13 
SCE's decommissioning costs(166)(222)56 
(113)(182)69 
Net cash provided by investing activities:
Proceeds from sale of investments6,219 5,019 1,200 
Purchases of investments(6,098)(4,898)(1,200)
121 121 — 
Net cash inflow (outflow)$8 $(61)$69 
Net cash used in operating activities relates to interest and dividends less administrative expenses, taxes and SCE's decommissioning costs. Investing activities represent the purchase and sale of investments within the nuclear decommissioning trusts, including the reinvestment of earnings from nuclear decommissioning trust investments.
Funds for decommissioning costs are requested from the nuclear decommissioning trusts one month in advance. Decommissioning disbursements are funded from sales of investments of the nuclear decommissioning trusts. The net cash impact reflects timing of decommissioning payments ($166 million and $222 million in 2025 and 2024, respectively) and reimbursements to SCE from the nuclear decommissioning trust ($176 million and $214 million in 2025 and 2024, respectively). The net cash outflow in 2024 also primarily includes $19 million of tax benefits received and a $30 million disallowance under the 2021 NDCTP (For further details, see "—Decommissioning of San Onofre), both contributed by SCE to the decommissioning trust.
24
Table of Contents
Edison International Parent and Other
The table below sets forth condensed historical cash flow from operations for Edison International Parent and Other, including intercompany eliminations.
Years ended December 31,Change
(in millions)202520242025 vs. 2024
Net cash used in operating activities$(352)$(369)$17 
Net cash provided by financing activities302 360 (58)
Net cash used in investing activities(6)(6)— 
Net decrease in cash, cash equivalents and restricted cash$(56)$(15)$(41)
Net Cash Used in Operating Activities
Net cash used in operating activities decreased by $17 million in 2025 compared to 2024. This is primarily due to $77 million intercompany tax settlement from SCE, partially offset by $50 million wildfire-related claims and related legal expenses paid by EIS to SCE (for further information, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides"), and $10 million higher interest and operating costs.
Net Cash Provided by Financing Activities
Net cash provided by financing activities was as follows:
Years ended December 31,Change
(in millions)202520242025 vs. 2024
Dividends paid to Edison International common shareholders$(1,274)$(1,198)$(76)
Dividends paid to Edison International preferred shareholders(104)(88)(16)
Dividends received from SCE2,220 1,440 780 
Capital contributions to SCE— (500)500 
Receipt from stock option exercises22 206 (184)
Long-term debt issuance, net of discount and issuance costs540 1,042 (502)
Long-term debt repayments(800)(500)(300)
Issuance of short-term debt850 — 850 
Repayments of short-term debt(101)(15)(86)
Common stock repurchased(32)(200)168 
Preferred stock repurchased(1,160)(28)(1,132)
Commercial paper financing, net158 214 (56)
Other(17)(13)(4)
Net cash provided by financing activities$302 $360 $(58)
25
Table of Contents
Contractual Obligations and Contingencies
Contractual Obligations
SCE and Edison International Parent and Other have various contractual obligations, which are recorded as liabilities in the consolidated financial statements. Other items, such as certain purchase commitments and other executory contracts, are not recognized as liabilities in the consolidated financial statements but are required to be disclosed in the footnotes to the financial statements.
For details on long-term debt, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
Certain power purchase agreements which SCE entered into with independent power producers are treated as operating or finance leases. In addition, SCE has other operating lease obligations primarily related to vehicles, office space and other equipment. For further discussion, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies" and "—Note 13. Leases."
SCE also has other purchase obligations primarily related to maintaining reliability and expanding SCE's transmission and distribution system and nuclear fuel supply contracts. For further discussion, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies."
Edison International Parent and Other and SCE have estimated contributions to the pension and PBOP plans. These amounts represent estimates that are based on assumptions that are subject to change. See "Notes to Consolidated Financial Statements—Note 9. Compensation and Benefit Plans" for further information.
Edison International and SCE have a total net liability recorded for uncertain tax positions. Edison International and SCE cannot make reliable estimates of the cash flows by period due to uncertainty surrounding the timing of resolving these open tax issues with the tax authorities. See "Notes to Consolidated Financial Statements—Note 8. Income Taxes" for further information.
For details on derivative obligations and asset retirement obligations, see "Notes to Consolidated Financial Statements—Note 6. Derivative Instruments" and "—Note 1. Summary of Significant Accounting Policies," respectively.
Contingencies
Edison International's and SCE's material contingencies are discussed in "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies."
Off-Balance Sheet Arrangements
SCE has variable interests in power purchase contracts with variable interest entities. See "Notes to Consolidated Financial Statements—Note 3. Variable Interest Entities."
MARKET RISK EXPOSURES
Edison International's and SCE's primary market risks include fluctuations in interest rates, commodity prices and volumes, investment prices, and counterparty credit.
Interest Rate Risk
Edison International and SCE are exposed to changes in interest rates primarily as a result of financing, investing and borrowing activities used for liquidity purposes, and to fund business operations and capital investments. The nature and amount of Edison International's and SCE's long-term and short-term debt can be expected to vary as a result of future business requirements, market conditions and other factors. Fluctuations in interest rates can affect earnings and cash flows. Changes in interest rates may impact SCE's authorized rate of return for the period beyond 2026 through a CPUC cost of capital proceeding, see "Business—SCE—Overview of Ratemaking Process" for further discussion. The following
26
Table of Contents
table summarizes the increase or decrease to the fair value of long-term debt including the current portion, if the market interest rates were changed while leaving all other assumptions the same:
(in millions)Carrying ValueFair Value10% Increase10% Decrease
Edison International:
December 31, 2025$37,998$35,721$34,265$37,315
December 31, 202435,58333,16031,84534,596
SCE:
December 31, 202533,18330,74429,42832,185
December 31, 202430,51527,99426,82729,267
Commodity Price Risk
SCE and its customers are exposed to the risk of a change in the market price of natural gas, electric power and transmission congestion. Due to regulatory mechanisms, exposure to commodity prices is not expected to impact earnings but may impact timing of cash flows. SCE's hedging program is designed to reduce exposure to variability in market prices related to SCE's purchases and sales of electric power and natural gas. As part of this program, SCE enters into swaps, forward arrangements, and congestion revenue rights ("CRRs"). The transactions are pre-approved by the CPUC or executed in compliance with CPUC-approved procurement plans. Therefore, SCE expects recovery of its related hedging costs, as well as procurement costs, through the ERRA balancing account or CPUC-approved procurement plans. For more details of the ERRA balancing account, see "Business—SCE—Overview of Ratemaking Process."
Fair Value of Derivative Instruments
The fair value of derivative instruments is included in the consolidated balance sheets unless subject to an exception under the applicable accounting guidance. Realized gains and losses from derivative instruments are expected to be recovered from or refunded to customers through regulatory mechanisms and, accordingly, changes in the fair value of derivative instruments have no impact on earnings. SCE does not use hedge accounting for these transactions due to this regulatory accounting treatment. For further discussion on fair value measurements and the fair value hierarchy, see "Notes to Consolidated Financial Statements—Note 4. Fair Value Measurements."
The fair value of outstanding derivative instruments used to mitigate exposure to commodity price risk was a net asset of $48 million and $212 million at December 31, 2025 and 2024, respectively.
The following table summarizes the increase or decrease to the fair values of the net asset of derivative instruments included in the consolidated balance sheets, if the electricity prices or gas prices were changed while leaving all other assumptions constant:
December 31,
(in millions)20252024
Increase in electricity prices by 10%$15 $34 
Decrease in electricity prices by 10%(15)(34)
Increase in gas prices by 10%1 1 
Decrease in gas prices by 10%(1)(1)
Investment Price Risk
Edison International and SCE are subject to investment price risk due to securities held as investments in the nuclear decommissioning trust and various pension and other post-retirement benefit plan trusts.
Nuclear Decommissioning Trust
As of December 31, 2025, SCE's nuclear decommissioning trust investments include equity investments of $1.9 billion and fixed income investments of $2.6 billion. These investments are exposed to price fluctuations in equity markets and changes in interest rates, as well as credit risk. SCE's investment policies and CPUC requirements place limitations on the types and investment grade ratings of the securities that may be held by the nuclear decommissioning trust. These policies restrict the trust from holding alternative investments and limit the trust funds' exposures to investments in highly illiquid markets. Due to regulatory mechanisms, investment earnings and realized and unrealized gains and losses increase or decrease the trust assets and the related regulatory asset or liability, and do not materially affect earnings. For further
27
Table of Contents
discussion on the nuclear decommissioning trust investments, see "Notes to Consolidated Financial Statements—Note 4. Fair Value Measurements" and "—Note 10. Investments."
PBOP and Pension Plan Assets
The PBOP Plan and the Southern California Edison Company Retirement Plan Trust assets include investments in equity securities, U.S. treasury securities, other fixed-income securities, common/collective funds, mutual funds, other investment entities, foreign exchange and interest rate contracts, and partnership/joint ventures. These investments are exposed to price fluctuations in equity markets and changes in interest rates, as well as credit risk. The investment of plan assets is overseen by a fiduciary investment committee. Risk is managed through diversification among multiple asset classes, managers, styles, and securities. See "Notes to Consolidated Financial Statements—Note 9. Compensation and Benefit Plans" for additional information regarding investment strategy of plan assets.
Contributions related to SCE employees made to SCE pension plan are anticipated to be recovered through CPUC-approved regulatory mechanisms.
Credit Risk
Credit risk exposure from counterparties for power and gas trading activities is measured as the sum of net accounts receivable (accounts receivable less accounts payable) and the current fair value of net derivative assets (derivative assets less derivative liabilities) reflected on the consolidated balance sheets. SCE enters into master agreements which typically provide for a right of set-off. Accordingly, SCE's credit risk exposure from counterparties is based on a net exposure under these arrangements. SCE manages the credit risk on the portfolio of counterparties based on credit ratings and other publicly disclosed information, such as financial statements, regulatory filings and press releases, to guide it in the process of setting credit levels, risk limits and contractual arrangements, including master netting agreements. Based on SCE's policies and risk exposures related to credit, SCE does not anticipate a material adverse effect on their financial statements as a result of counterparty nonperformance. At December 31, 2025, SCE's power and gas trading counterparty credit risk exposure was $3 million, 31.7% of which was associated to counterparties with an investment grade rating of A or higher and 67.2% was associated with a CPUC approved electronic broker and exchange platform operating under a rigorous risk management framework.
For more information related to credit risks, see "Notes to Consolidated Financial Statements—Note 6. Derivative Instruments."
CRITICAL ACCOUNTING ESTIMATES AND POLICIES
The accounting policies described below are considered critical to obtaining an understanding of Edison International's and SCE's consolidated financial statements because their application requires the use of significant estimates and judgments by management in preparing the consolidated financial statements. Management estimates and judgments are inherently uncertain and may differ significantly from actual results achieved. Management considers an accounting estimate to be critical if the estimate requires significant assumptions and changes in the estimate or, the use of alternative estimates, could have a material impact on Edison International's and SCE's results of operations or financial position. For more information on Edison International's and SCE's accounting policies, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies."
Accounting for Contingencies
Nature of Estimates Required. Edison International and SCE record loss contingencies when management determines that the outcome of future events is probable of occurring and when the amount of the loss can be reasonably estimated. Gain contingencies are recognized in the financial statements when they are realized.
Key Assumptions and Approach Used. The determination of an accrual for a loss contingency is based on management judgment and estimates with respect to the likely outcome of the matter, including the analysis of different scenarios. Recorded liabilities are adjusted when events or circumstances cause these judgments or estimates to change. In assessing whether a loss is probable, reasonably possible, or remote, Edison International and SCE may consider the following factors, among others: the nature of the litigation, claim or assessment, opinions or views of legal counsel and other advisors, and the experience gained from similar cases. For material contingencies when there is a reasonable possibility that a loss or an additional loss may be incurred, Edison International and SCE disclose the nature of the contingency and an estimate of the possible loss or range of loss or a statement that such an estimate cannot be made.
Effect if Different Assumptions Used. Actual amounts realized upon settlement of contingencies may be different than amounts recorded and disclosed and could have a significant impact on the liabilities, revenue and expenses recorded on the consolidated financial statements. For a discussion of contingencies, guarantees, and indemnities, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies."
28
Table of Contents
Application to Wildfires
As discussed in "Management Overview," wildfires in SCE's service area have caused loss of life, substantial damage to both residential and business properties, and service outages for SCE customers.
The extent of legal liability for wildfire-related damages in actions against utilities depends on a number of factors, including whether the utility substantially caused or contributed to the damages and whether parties seeking recovery of damages will be required to show negligence in addition to causation. Final determinations of legal liability for wildfire events, including determinations of whether SCE was negligent, would only be made during lengthy and complex litigation processes and settlements may be reached before determinations of legal liability are ever made.
Edison International and SCE may be unable to estimate a reasonably possible loss or range of losses that could be incurred in connection with a wildfire, including those where a loss is probable, due to the complexities associated with estimating damages, such as making judgments for which no reasonably substantive basis exists and which require significant speculation about the conduct of litigation counterparties. The large number and varying types of claims, including individual claims, subrogation claims, and claims from public entities, and the interrelationship among these claims, for example, levels of insurance held by claimants, can create additional estimation complexity and uncertainty. Management's ability to develop a reasonable estimate improves as information about the scope of the loss becomes more fully developed, key factual and legal issues are resolved, and as additional information becomes available through settlement and litigation processes.
Estimated losses for wildfire events are based on a number of assumptions and are subject to change as additional information becomes available. Those assumptions include volume of claims, damages asserted and associated loss, opinions of counsel regarding litigation risk, the status of and developments in the course of litigation, prior experience litigating and settling wildfire litigation claims, the amount of insurance that may offset losses, and estimating contributory liabilities from third parties who may be responsible for portions of loss. Actual losses incurred may be higher or lower than estimated based on several factors, including the uncertainty in estimating damages that have been or may be alleged. For instance, SCE will receive additional information with respect to damages claimed as the claims mediation and trial processes progress. Other factors that can cause actual losses incurred to be higher or lower than estimated include the ability to reach settlements and the outcomes of settlements reached through the ongoing claims mediation and trial processes, uncertainties related to the sufficiency of insurance held by plaintiffs and potential plaintiffs, uncertainties related to the litigation processes, including whether plaintiffs will ultimately pursue claims, uncertainty as to the legal and factual determinations to be made during litigation, including uncertainty as to the contributing causes of certain wildfires, and the uncertainty as to how these factors impact future settlements.
For more information related to the loss contingencies of the wildfires, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
Rate Regulated Enterprises
Nature of Estimate Required. SCE follows the accounting principles for rate-regulated enterprises which are required for entities whose rates are set by regulators at levels intended to recover the estimated costs of providing service, plus a return on net investment, or rate base. Regulators may also impose penalties or grant incentives. Due to timing and other differences in the collection of revenue, these accounting principles allow a cost that would otherwise be charged as an expense by an unregulated entity to be capitalized as a regulatory asset if it is probable that such cost is recoverable through future rates; conversely the accounting principles require creation of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. In addition, SCE recognizes revenue and regulatory assets from alternative revenue programs, which enables the utility to adjust future rates in response to past activities or completed events, if certain criteria are met.
Accounting principles for rate-regulated enterprises also require recognition of an impairment loss if it becomes probable that the regulated utility will abandon a plant investment or the cost of a recently completed plant will be disallowed for ratemaking purposes, and a reasonable estimate of the amount of the disallowance can be made.
Key Assumptions and Approach Used. SCE's management assesses at the end of each reporting period whether regulatory assets are probable of future recovery by considering factors such as the current regulatory environment, the issuance of rate orders on recovery of the specific or a similar incurred cost to SCE or other rate-regulated entities, and other factors that would indicate that the regulator will treat an incurred cost as allowable for ratemaking purposes. Using these factors, management has determined that existing regulatory assets are probable of future recovery or settlement, and regulatory liabilities are properly identified. This determination reflects the current regulatory climate and is subject to change in the future. SCE also considers whether any plant investments are probable of abandonment or disallowance.
Effect if Different Assumptions Used. Significant management judgment is required to evaluate the anticipated recovery of regulatory assets and plant investments, the recognition of incentives and revenue subject to refund, as well as the
29
Table of Contents
anticipated cost of regulatory liabilities or penalties. If future recovery of costs ceases to be probable, all or part of the regulatory assets and/or plant investments would have to be written off against current period earnings, and additional regulatory liabilities would have to be recognized. At December 31, 2025, the consolidated balance sheets included regulatory assets of $16.3 billion and regulatory liabilities of $11.8 billion. If different judgments were reached on recovery of costs and timing of income recognition, SCE's earnings may vary from the amounts reported.
Application to Southern California Wildfires
Application to post-AB 1054 Wildfires
Management judgment is required to assess the probability of recovery of SCE's losses realized, in excess of available insurance, in connection with wildfires ignited after the adoption of AB 1054 in July 2019.
The CPUC and FERC may not allow SCE to recover uninsured losses through electric rates if it is determined that such losses were not reasonably or prudently incurred. The California Wildfire Legislation clarified that the CPUC must allow recovery of costs and expenses arising from a covered wildfire if the utility's conduct related to the ignition was consistent with actions that a reasonable utility would have undertaken in good faith under similar circumstances, at the relevant point in time, and based on the information available at that time. Further, utilities with a valid safety certification at the time of the relevant wildfire will be presumed to have acted prudently related to a wildfire ignition unless a party in the cost recovery proceeding creates "serious doubt" as to the reasonableness of the utility's conduct, at which time, the burden shifts back to the utility to dispel that doubt and prove its conduct was prudent. The serious doubt standard in the California Wildfire Legislation is modeled after the FERC cost recovery standard. SCE evaluates the probability of recovery of costs related to the Other Wildfire Events and the Eaton Fire that ignited after the adoption of the California Wildfire Legislation in the context of the prudency standard laid out by the California Wildfire Legislation above, including how the FERC applies the serious doubt standard. SCE’s evaluation also relies on its status as a holder of a valid safety certification, facts and other evidence known to date related to the ignition, and any regulatory decisions illustrating the interpretation and/or application of the prudency framework under the California Wildfire Legislation, which as of December 31, 2025, has not been applied by the CPUC to an actual cost recovery application filed by any California investor-owned utility. SCE also considers which costs are eligible for recovery based on precedent from other CPUC cost recovery proceedings. Management's assessment of the probability of recovery may change, related to changes in any of these factors in the future.
See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides" for further discussion of regulatory assets recorded for wildfire as of December 31, 2025.
Income Taxes
Nature of Estimates Required. As part of the process of preparing its consolidated financial statements, Edison International and SCE are required to estimate income taxes for each jurisdiction in which they operate. This process involves estimating actual current period tax expense together with assessing temporary differences resulting from differing treatment of items, such as depreciation, for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are included within Edison International's and SCE's consolidated balance sheets, including net operating loss and tax credit carryforwards. Certain estimates and assumptions are required to determine whether deferred tax assets can and will be utilized in future periods. Based on currently enacted tax laws, Edison International expects to generate sufficient taxable income to fully utilize all loss and credit carryovers set to expire beyond 2025.
Edison International and SCE take certain tax positions they believe are in accordance with the applicable tax laws. However, these tax positions are subject to interpretation by the Internal Revenue Service, state tax authorities and the courts. Edison International and SCE determine uncertain tax positions in accordance with the authoritative guidance.
Key Assumptions and Approach Used. In determining whether it is more likely than not that all or some portion of net operating loss and tax credit carryforwards can be utilized, management analyzes the trend of GAAP earnings and then estimates the impact of future taxable income, reversing temporary differences and available prudent and feasible tax planning strategies based on currently enacted tax laws.
Accounting for tax obligations requires management judgment. Edison International's and SCE's management use judgment in determining whether the evidence indicates it is more likely than not, based solely on the technical merits, that a tax position will be sustained, and to determine the amount of tax benefits to be recognized. Judgment is also used in determining the likelihood a tax position will be settled and possible settlement outcomes. In assessing uncertain tax positions Edison International and SCE consider, among others, the following factors: the facts and circumstances of the position, regulations, rulings, case law, opinions or views of legal counsel and other advisers, and the experience gained from similar tax positions. Edison International and SCE evaluate uncertain tax positions at the end of each reporting period and make adjustments when warranted based on changes in fact or law.
30
Table of Contents
Effect if Different Assumptions Used. Should a change in facts or circumstances, including a change in enacted tax legislation, lead to a change in judgment about the ultimate realizability of a deferred tax asset, Edison International and SCE would record or adjust the related valuation allowance in the period that the change in facts and circumstances occurs, along with a corresponding increase or decrease in the provision for income taxes.
Actual income taxes may differ from the estimated amounts which could have a significant impact on the liabilities, revenue, and expenses recorded in the financial statements. Edison International and SCE continue to be under audit or subject to audit for multiple years in various jurisdictions. Significant judgment is required to determine the tax treatment of particular tax positions that involve interpretations of complex tax laws. Such liabilities are based on judgment and a final determination could take many years from the time the liability is recorded. Furthermore, settlement of tax positions included in open tax years may be resolved by compromises of tax positions based on current factors and business considerations that may result in material adjustments to income taxes previously estimated. For a discussion of current and deferred taxes, net operating losses and tax credit carryforwards, accounting for uncertainty in income taxes, unrecognized tax benefits, and tax disputes, see "Notes to Consolidated Financial Statements—Note 8. Income Taxes."
Nuclear Decommissioning – Asset Retirement Obligation
Key Assumptions and Approach Used. Units 1, 2, and 3 decommissioning cost estimates are updated in each NDCTP and when there are material changes to the timing or amount of estimated future cash flows. Palo Verde decommissioning cost estimates are updated by the operating agent, Arizona Public Services, every three years and when there are material changes to the timing or amount of estimated future cash flows. SCE estimates that it will spend approximately $7.4 billion, undiscounted through 2098, to decommission its nuclear facilities.
The current ARO estimates for San Onofre and Palo Verde are based on:
•Decommissioning Costs. The estimated costs for labor, material, equipment and other, and low-level radioactive waste costs are included in each of the NRC decommissioning stages: license termination, site restoration and spent fuel storage. The liability to decommission SCE's nuclear power facilities is based on a 2024 decommissioning study, filed as part of the 2024 NDCTP, for Units 1, 2, and 3 and a 2023 decommissioning study for Palo Verde.
•Escalation Rates. Annual escalation rates are used to convert the decommissioning cost estimates in base year dollars to decommissioning cost estimates in future-year dollars. Escalation rates are primarily used for labor, material, equipment, and low-level radioactive waste burial costs. SCE's current estimates are based upon SCE's decommissioning cost methodology used for ratemaking purposes. Average escalation rates range from 2.1% to 7.5% (depending on the cost element) annually.
•Timing. Initial decommissioning activities at Unit 1 started in 1999 and at Units 2 and 3 in 2013. Cost estimates for San Onofre Units are currently based on completion of decommissioning activities by 2056. Cost estimates for Palo Verde are based on an assumption that decommissioning will commence promptly after the current NRC operating licenses expire. The Palo Verde 1, 2, and 3 operating licenses currently expire in 2045, 2046, and 2047, respectively.
•Spent Fuel Dry Storage Costs. Cost estimates, including the impact of escalations, are based on an assumption that the U.S. Department of Energy will begin to take spent fuel from the nuclear industry in 2034 and will remove the last spent fuel from the San Onofre and Palo Verde sites by 2054 and 2097, respectively.
•Changes in Decommissioning Technology, Regulation and Economics. The current cost studies assume the use of current technologies under current regulations and at current cost levels.
See "Liquidity and Capital Resources—SCE—Decommissioning of San Onofre" for further discussion of the plans for decommissioning of San Onofre.
Effect if Different Assumptions Used. The ARO for decommissioning SCE's nuclear facilities was $2.0 billion as of December 31, 2025, based on the most recent decommissioning studies performed and the subsequent cost estimate updates. Changes in the estimated costs, execution strategy or timing of decommissioning, or in the assumptions and judgments by management underlying these estimates, could cause material revisions to the estimated total cost to decommission these facilities which could have a material effect on the recorded liability.
The following table illustrates the increase to the ARO liability if the cost escalation rate was adjusted while leaving all other assumptions constant:
(in millions)
Increase to ARO at
December 31, 2025
Uniform increase in escalation rate of 1 percentage point$582 
31
Table of Contents
The increase in the ARO liability driven by an increase in the escalation rate would result in a decrease in the regulatory liability for recoveries in excess of ARO liabilities. As of December 31, 2025, the regulatory liability for recoveries in excess of ARO liabilities was $2.1 billion.
Pensions and Postretirement Benefits Other than Pensions
Nature of Estimate Required. Authoritative accounting guidance requires companies to recognize the overfunded or underfunded status of defined benefit pension and other postretirement plans as assets and liabilities in the balance sheet; the assets and/or liabilities are normally offset through other comprehensive income (loss). In accordance with authoritative guidance for rate-regulated enterprises, regulatory assets and liabilities are recorded instead of charges and credits to other comprehensive income (loss) for its postretirement benefit plans that are recoverable in utility rates. Edison International and SCE have a fiscal year-end measurement date for all of their postretirement plans.
Key Assumptions of Approach Used. Pension and other postretirement benefit obligations and the related effects on results of operations are calculated using actuarial models. Two critical assumptions, discount rate and expected return on assets, are important elements of plan expense, and the discount rate is important to liability measurement. Other assumptions, which require management judgment, include the rate of compensation increases, and rates of retirement, turnover and termination. Additionally, health care cost trend rates are critical assumptions for postretirement health care plans. These critical assumptions are evaluated periodically and updated to reflect actual experience, as appropriate.
As of December 31, 2025, Edison International's and SCE's pension plans had a $3.7 billion and $3.4 billion projected benefit obligation, respectively, and total 2025 expense for these plans was $30 million and $26 million, respectively. As of December 31, 2025, the accumulated benefit obligation for Edison International's and SCE's PBOP plans were $749 million and $745 million, respectively, and there were $12 million and $11 million benefit for Edison International's and SCE's PBOP plans for 2025, respectively. The majority of annual contributions made to SCE's pension and PBOP plan are anticipated to be recovered through CPUC-approved regulatory mechanisms and are expected to be, at a minimum, equal to the related annual expense.
Pension expense is recorded for SCE based on the amount funded to the trusts, as calculated using an actuarial method required for ratemaking purposes, in which the impact of market volatility on plan assets is recognized in earnings on a more gradual basis. Any difference between pension expense calculated in accordance with ratemaking methods and pension expense calculated in accordance with authoritative accounting guidance for pension is accumulated as a regulatory asset or liability, and is expected, over time, to be recovered from or returned to customers. As of December 31, 2025, this cumulative difference amounted to $157 million, meaning that the ratemaking method has recognized less in expense than the accounting method since implementation of authoritative guidance for employers' accounting for pensions in 1987, which was offset by a regulatory liability for the current funding level of SCE's pension plan.
Edison International and SCE used the following critical assumptions to determine expense for pension and PBOP for 2025:
(in millions)Pension
Plans		PBOP
Plans
Discount rate1
5.56 %5.60 %
Expected long-term return on plan assets2
6.75 %4.72 %
Assumed health care cost trend rates3
*6.50 %
*Not applicable to pension plans.
1The discount rate enables Edison International and SCE to state expected future cash flows at a present value on the measurement date. Edison International and SCE select its discount rate by performing a yield curve analysis. This analysis determines the equivalent discount rate on projected cash flows by matching the timing and amount of expected future benefit payments to the corresponding yields from the Willis Towers Watson RATE: Link 10th – 90th percentile yield curve model on the measurement date.
2To determine the expected long-term rate of return on pension plan assets, current and expected asset allocations are considered, as well as historical and expected returns on plan assets. A portion of PBOP trusts asset returns are subject to taxation, so the rate of return on plan assets above is determined on an after-tax basis. Actual time-weighted, annualized returns on the pension plan assets were 11.6%, 4.4%, and 7.7% for the one-year, five-year and ten-year periods ended December 31, 2025, respectively. Actual time-
32
Table of Contents
weighted, annualized returns on the PBOP plan assets were 7.3%, 0.6%, and 4.7% over these same periods. Accounting principles provide that differences between expected and actual returns are recognized over the average future service of employees.
3The health care cost trend rate gradually declines to 5.00% for 2031 and beyond.
As of December 31, 2025, Edison International and SCE had unrecognized net pension gains of $173 million and $141 million, respectively, and unrecognized PBOP gains of $1.7 billion. The unrecognized pension and PBOP gains primarily consisted of the cumulative impact of the increased discount rates on the respective benefit obligations and the cumulative difference between the expected and actual rate of return on plan assets. Of these deferred gains, $158 million of SCE's pension gains and $1.7 billion of SCE's PBOP gains are recorded as regulatory liabilities, respectively, and are expected to be amortized to expense over the expected future service of the employees (subject to regulatory adjustment) or refunded to ratepayers at the termination or completion of the plan.
Edison International's and SCE's pension and PBOP plans are subject to limits established for federal tax deductibility. SCE funds its pension and PBOP plans in accordance with amounts allowed by the CPUC. Executive pension plans have no plan assets.
Effect if Different Assumptions Used. Changes in the estimated costs or timing of pension and other postretirement benefit obligations, or the assumptions and judgments used by management underlying these estimates, could have a material effect on the recorded expenses and liabilities.
The following table summarizes the increase or decrease to projected benefit obligation for pension and the accumulated benefit obligation for PBOP if the discount rate were changed while leaving all other assumptions constant:
Edison InternationalSCE
(in millions)Increase in
discount rate
by 1%		Decrease in
discount rate
by 1%		Increase in
discount rate
by 1%		Decrease in
discount rate
by 1%
Change to projected benefit obligation for pension$(116)$138$(94)$111
Change to accumulated benefit obligation for PBOP(70)83(70)83
A one percentage point increase in the expected rate of return on pension plan assets would decrease Edison International's and SCE's current year expense by $36 million and $34 million, respectively, and a one percentage point increase in the expected rate of return on PBOP plan assets would decrease both Edison International's and SCE's current year expense by $24 million.
Contributions to the Wildfire Fund
Nature of Estimates Required. At December 31, 2025, Edison International and SCE have a $1.7 billion long-term asset and a $138 million current asset reflected as "Wildfire Fund contributions" in the consolidated balance sheets for the initial $2.4 billion contribution made during 2019 and the present value of annual contributions SCE committed to make to the Wildfire Fund, reduced by amortization. At December 31, 2025, a long-term liability of $274 million has been reflected in "Other deferred credits and other long-term liabilities" for the present value of unpaid contributions. Contributions were discounted to the present value using US treasury interest rates at the date SCE committed to participate in the Wildfire Fund.
Management concluded it would be most appropriate to account for the contributions to the Wildfire Fund similar to prepaid insurance, ratably allocating the expense to periods based on an estimated period of coverage.
Key Assumptions and Approach Used. The Wildfire Fund does not have a defined life and instead, will terminate when the fund administrator determines that the fund has been exhausted. Estimating the period of coverage of the fund requires significant judgment. Frequency of wildfire events and estimated costs associated with wildfire events caused by participating utilities are among the significant factors used to estimate the fund's period of coverage.
SCE reassess the period of coverage of the fund at least annually in the first quarter each year and when new or additional information becomes available. As of the date of this filing, after considering the current accrued losses for the Eaton Fire, SCE does not have new or additional information that would enable it to change its prior assessment that the Wildfire Fund would provide coverage for an estimated 20 years from the date SCE committed to participate in the Wildfire Fund. When updating its estimate, SCE includes all its fires for which losses can be reasonably estimated, and relies on publicly disclosed wildfire-related losses related to other participating utilities. As discussed in "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides," while SCE believes that it will incur material losses in connection with the Eaton Fire, it is currently unable to reasonably estimate a range of losses that may be incurred. The Wildfire Fund amortization period will be evaluated and adjusted as
33
Table of Contents
new or additional information on contributions and wildfire events, including reasonably estimated losses related to the Eaton Fire, becomes available.
Edison International and SCE adjust the period of coverage on a prospective basis and amortize the Wildfire Fund contribution asset ratably over the remaining estimated life of the fund. An impairment will be recorded to the Wildfire Fund contribution asset, if the asset exceeds SCE's ability to benefit from the remaining coverage provided by the Wildfire Fund.
In 2025, management determined that the period of coverage for the Wildfire Fund, based on available historical data from wildfires caused by electrical utility equipment to estimate expected loss, the current accrued losses for the Eaton Fire, as well as based on the fact that it is currently unable to reasonably estimate the range of losses associated with the Eaton Fire, continues to be an estimated 20 years from the date SCE committed to participate in the Wildfire Fund.
Effect if Different Assumptions Used. Changes in the estimated life of the Wildfire Fund, including impairment of the fund, could have a material impact on the expense recognition.
NEW ACCOUNTING GUIDANCE
New accounting guidance is discussed in "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—New Accounting Guidance."
RISK FACTORS
RISKS RELATING TO EDISON INTERNATIONAL
Edison International's liquidity and ability to pay dividends depends on its ability to borrow funds, access to bank and capital markets, monetization of tax benefits held by Edison International, and SCE's ability to pay dividends and tax allocation payments to Edison International. Edison International is a holding company and, as such, it has no material operations of its own. Edison International's ability to meet its financial obligations, make investments, and to pay dividends on its common stock is primarily dependent on the earnings and cash flows of SCE and SCE's ability to make upstream distributions. If SCE does not make upstream distributions to Edison International and Edison International is unable to access the bank and capital markets on reasonable terms, Edison International may be unable to continue to pay dividends to its shareholders or meet its financial obligations.
Prior to paying dividends to Edison International, SCE has financial and regulatory obligations that must be satisfied, including, among others, debt service and preference stock dividends. Further, Edison International and SCE cannot pay dividends if California law requirements for the declaration of dividends are not met. For information on CPUC and California law requirements related to the declaration of dividends, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends." SCE may also owe tax-allocation payments to Edison International under applicable tax-allocation agreements.
Edison International's ability to obtain financing, as well as its ability to refinance debt and make scheduled payments of principal and interest, are dependent on numerous factors, including its levels of indebtedness, maintenance of acceptable credit ratings, financial performance, liquidity and cash flow, and other market conditions. In addition, the factors affecting SCE's business will impact Edison International's ability to obtain financing. Edison International's inability to borrow funds from time to time could have a material effect on Edison International's liquidity and operations.
See "Risks Relating to Southern California Edison Company" below for further discussion.
RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY
Regulatory and Legislative Risks
SCE's financial results depend upon its ability to recover its costs and to earn a reasonable rate of return on capital investments in a timely manner from its customers through regulated rates.
SCE's ongoing financial results depend on its ability to recover its costs from its customers, including the costs of electricity purchased for its customers, through the rates it charges its customers as approved by the CPUC and FERC. SCE's financial results also depend on its ability to earn a reasonable return on capital, including long-term debt and equity. SCE's ability to recover its costs and earn a reasonable rate of return can be affected by many factors, including the time lag between when costs are incurred and when those costs are recovered in customers' rates and differences between the forecast or authorized costs embedded in rates (which are set on a prospective basis) and the amount of actual costs incurred.
The CPUC or the FERC may not allow SCE to recover costs on the basis that such costs were not reasonably or prudently incurred or for other reasons. Further, SCE may incur expenses before the relevant regulatory agency approves the
34
Table of Contents
recovery of such costs. For example, SCE has incurred, and expects to further incur, wildfire mitigation expenses before it is clear whether such costs will be recoverable from customers. Also, the CPUC may deny recovery of costs incurred by SCE, including uninsured wildfire-related costs, if the CPUC determines that SCE was not prudent. For further information on recovery of uninsured wildfire-related costs see "Business—Southern California Wildfires—Recovery of Wildfire-Related Costs" and "Management Overview—Southern California Wildfires and Mudslides" in the MD&A. In addition, while SCE supports California's environmental goals, it may be prevented from fully executing on its strategy to support such goals by regulatory delay or lack of approval of cost-recovery for the costs of such strategic actions and electrification programs from the relevant regulatory agencies, including as a result of customer affordability concerns. For example, in the 2025 GRC final decision, the CPUC denied 50% of SCE’s requested upfront funding for its Transportation Electrification Grid Readiness program, citing uncertain market conditions and considering intervenor positions, many of which raised affordability concerns.
SCE's CPUC authorized return on investment is established by multiplying an authorized rate of return, determined by the CPUC in standalone cost of capital proceedings, by SCE's authorized CPUC rate base. SCE's CPUC-authorized cost of capital is subject to potential adjustment should interest rates move substantially in years between cost of capital proceedings. SCE's authorized return on its transmission assets is established by multiplying an authorized rate of return, determined by the FERC, by SCE's transmission rate base. For further information see "Business—SCE—Overview of Ratemaking Process."
SCE's capital investment plan, increasing procurement of renewable power and energy storage, inflation, commodity price volatility, increasing self-generation, load departures to CCAs or Electric Service Providers, and increasing environmental regulations, among other things, collectively place continuing upward pressure on customer rates. As customer rates increase, the CPUC may face greater pressure to approve lesser amounts in SCE’s ratemaking or cost recovery proceedings. To relieve some of this upward rate pressure, the CPUC may authorize lower revenues, or increase the period over which SCE is allowed to recover amounts, or disallow the recovery of SCE’s cost which could impact SCE’s ability to recover its operating costs timely or at all. If SCE is unable to obtain a sufficient rate increase or modify its rate design to recover its costs and an adequate return on capital in rates in a timely manner, its financial condition and results of operations could be materially affected.
SCE is subject to extensive regulation and the risk of adverse regulatory and legislative decisions, delays in regulatory or legislative decisions, and changes in applicable regulations or legislation.
SCE operates in a highly regulated environment. SCE's business is subject to extensive federal, state and local energy, environmental and other laws and regulations. Among other things, the CPUC regulates SCE's retail rates and capital structure, and the FERC regulates SCE's wholesale rates and capital structure. The NRC regulates the decommissioning of San Onofre in addition to the local and state agencies that require permits. The construction, planning, siting and operation of SCE's power plants, energy storage projects, and transmission lines in California are also subject to regulation by the CPUC and other local, state and federal agencies.
SCE must periodically apply for licenses and permits from these various regulatory authorities, including environmental regulatory authorities, and must abide by their respective rules, regulations and orders. Should SCE be unsuccessful in obtaining necessary licenses or permits or should these regulatory authorities initiate any investigations or enforcement actions or impose fines, penalties or disallowances on SCE, SCE may be prevented from executing its strategy and its business could be materially affected. The process of obtaining licenses and permits from regulatory authorities may be delayed or defeated by opponents and such delay or defeat could have a material effect on SCE's business.
The Wildfire Fund and other provisions of the California Wildfire Legislation may not be sufficient or effectively mitigate the significant risk faced by California investor-owned utilities related to liability for damages arising from catastrophic wildfires where utility facilities are a substantial cause, which could have a detrimental effect on SCE's business and financial condition. The effectiveness of the California Wildfire Legislation to mitigate the wildfire-related risk faced by SCE is conditioned in part on the performance of OEIS and various entities formed under AB 1054 and related legislation to, among other things, administer the Wildfire Fund, approve WMPs, issue safety certifications, oversee and enforce compliance with wildfire safety standards, and develop metrics to reduce risk and measure compliance with risk reduction.
In addition, CPUC approval is required to recover the costs SCE is incurring to strengthen its wildfire mitigation and prevention efforts described in SCE's WMPs. See "Business—Southern California Wildfires" and "Liquidity and Capital Resources—SCE—Regulatory Proceedings—Wildfire Related Regulatory Proceedings" in the MD&A.
Existing regulations may be revised or re-interpreted and new laws and regulations may be adopted, via the public initiative or legislative process, or become applicable to SCE, or its facilities or operations, in a manner that may have a detrimental effect on SCE's business or result in significant additional costs.
35
Table of Contents
SCE's energy procurement activities are subject to regulatory and market risks, including availability, that could materially affect its financial condition and liquidity.
SCE obtains energy, capacity, environmental credits and ancillary services needed to serve its customers from its own generating plants and through contracts with energy producers and sellers. California law and CPUC decisions allow SCE to recover, through the rates it is allowed to charge its customers, reasonable procurement costs incurred in compliance with an approved procurement plan. Nonetheless, SCE's cash flows remain subject to volatility primarily resulting from changes in commodity prices, including as a result of gas supply constraints. Additionally, significant and prolonged gas use restrictions may adversely impact the reliability of the electric grid if critical generation resources are limited in their operations. For further information, see "Business—SCE—Purchased Power and Fuel Supply." SCE is also subject to the risks of unfavorable or untimely CPUC decisions about the compliance with SCE's energy procurement plan and the reasonableness of certain procurement-related costs.
SCE may not be able to hedge its risk for commodities on economic terms or fully recover the costs of hedges through the rates it is allowed to charge its customers, which could materially affect SCE's liquidity and results of operations, see "Market Risk Exposures" in the MD&A.
Operating Risks
Damage claims against SCE for wildfire-related losses may materially affect SCE's financial condition and results of operations.
Prolonged drought conditions and shifting weather patterns in California resulting from climate change as well as, among other things, buildup of dry vegetation in areas severely impacted by years of historic drought and lack of adequate clearing of hazardous fuels by responsible parties have increased the duration of the wildfire season and the risk of severe wildfire events.
Severe wildfires and urban development in and near high fire risk areas in California have given rise to large damage claims against California utilities for fire-related losses alleged to be the result of utility practices and/or the failure of electric and other utility equipment. Catastrophic wildfires can occur in SCE's service area even if SCE effectively implements its WMPs. California courts have previously found utilities to be strictly liable for property damage, regardless of fault, by applying the theory of inverse condemnation when a utility's facilities were determined to be a substantial cause of a wildfire that caused the property damage. An inability to recover uninsured wildfire-related costs could materially affect SCE's business, financial condition and results of operations. For example, if SCE is unable to, or believes that it may be unable to, recover damages related to catastrophic wildfires through insurance, the Wildfire Fund (which is only available for fires ignited after July 12, 2019) or electric rates, or access the bank and capital markets on reasonable terms, SCE may not have sufficient cash or equity to pay dividends or may be restricted from declaring such dividends because it does not meet CPUC or California law requirements related to the declaration of dividends. For information on the California law requirements on the declaration of dividends, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends." Also see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
Edison International's and SCE's costs of accessing capital markets have increased due to the risks associated with wildfires in Southern California. Edison International's and SCE's access to the bank and capital markets could also be constrained and/or the costs of accessing those markets could increase further as a result of wildfire risk, including if Edison International's and/or SCE's credit ratings are downgraded or placed on negative watch due to concerns about Edison International and/or SCE's financial health as a result of wildfires.
SCE's insurance coverage for wildfires may not be sufficient.
SCE may not be able to recover uninsured losses (including amounts paid for self-insured retention and co-insurance) in electric rates. Additionally, SCE’s contractors may experience coverage reductions and/or increased wildfire insurance costs in future years. For losses associated with claims occurring before the authorization of SCE’s CPUC-authorized customer-funded self-insurance program, no assurance can be given that losses will not exceed the limits of SCE's or its contractors' insurance coverage. Losses which are not fully insured or cannot be recovered from contractors, through the Wildfire Fund or electric rates, including any such losses that exceed funds available through the Wildfire Fund and are ultimately not authorized to be recovered through rates, could materially affect Edison International's and SCE's financial condition and results of operations. For more information on wildfire insurance risk, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
SCE may not effectively implement its wildfire mitigation plans.
SCE will face a higher likelihood of catastrophic wildfires in its service area if it cannot effectively implement its WMPs. For example, SCE may not be able to effectively implement its WMPs if it experiences unanticipated difficulties relative to
36
Table of Contents
permitting delays, sourcing, engaging, and retaining effectively trained contract workers or procuring materials it needs to fulfill its mitigation obligations under the WMPs. In addition, if SCE does not have an approved WMP, SCE will not be issued a safety certification from the CPUC and will consequently not benefit from the presumption of prudency or the Liability Cap. Furthermore, approval of a WMP by the OEIS does not ensure that the CPUC will authorize recovery of the associated costs. If the CPUC denies or limits cost recovery for work needed to execute an approved WMP, SCE may be required to absorb those costs or may need to reduce the scope or timing of its mitigation activities. For more information about the WMP process, see "Business—Southern California Wildfires— Safety Certification and Wildfire Mitigation Plan."
The CPUC may assess penalties on SCE if it finds that SCE has failed to substantially comply with its WMP. In addition, SCE may be subject to mandated changes to, or restrictions on, its operational wildfire mitigation practices or be subject to regulatory fines and penalties or claims for damages and reputational harm if SCE does not execute its wildfire mitigation practices in compliance with applicable rules and regulations. SCE's wildfire mitigation practices include PSPS and using fast-curve settings. In addition, SCE has been and may be further subject to regulatory fines and penalties or claims for damages and reputational harm if it is determined that SCE has placed excessive or unreasonable reliance on PSPS or has failed to maintain compliance with notification and post event reporting requirements related to PSPS. For information regarding SCE’s PSPS activities and related fines, see "Business—Southern California Wildfires—Public Safety Power Shutoff."
SCE establishes the criteria under which it implements PSPS in its service area. To the extent SCE's criteria for implementing PSPS are not sufficient to mitigate the risk of wildfires during high wind events, SCE does not fully implement PSPS when criteria are met due to other overriding conditions or SCE's regulators or others mandate changes to, or restrictions on, its criteria or other operational PSPS practices, SCE will face a higher likelihood of catastrophic wildfires in its service area during high wind events. Similarly, if SCE is prohibited by the CPUC from implementing its desired fast-curve settings, SCE will face a higher likelihood of catastrophic wildfires in its service area.
For more information on the presumption of prudency and the Liability Cap, see "Business—Southern California Wildfires—Recovery of Wildfire-Related Costs— California Wildfire Legislation."
SCE will not benefit from all of the features of the California Wildfire Legislation if the Wildfire Fund is exhausted.
Catastrophic wildfires could rapidly exhaust the Wildfire Fund and SCE will not be reimbursed by the Wildfire Fund or benefit from the Liability Cap if the fund has been exhausted as a result of damage claims previously incurred by SCE or the other participating utilities.
For more information on the California Wildfire Legislation , see "Business—Southern California Wildfires and Mudslides—Recovery of Wildfire-Related Costs—California Wildfire Legislation."
Climate change exacerbated weather-related incidents and other natural disasters have and could continue to materially affect SCE's financial condition and results of operations.
Weather-related incidents, including storms and events caused, or exacerbated, by climate change, such as wildfires, flooding and debris flows, and other natural disasters such as earthquakes can disrupt the generation and transmission of electricity, and can seriously damage the infrastructure necessary to deliver power to SCE's customers. The impacts of climate change continue to evolve and remain dynamic and unpredictable.
Climate change has caused, and exacerbated, extreme weather events and wildfires in southern California, and wildfires could cause, among other things, public safety issues, property damage and operational issues. In addition, the risk of flooding and debris flows occurring as a result of rain may be heightened. For example, the Eaton Fire that ignited in Los Angeles County in January 2025 resulted in loss of life, property damage and loss of service and subsequent extreme weather events such as increased rain or flooding could further impact the affected areas. If reimbursements from the Wildfire Fund for eligible claims related to the Eaton Fire are received later than projected, SCE could experience short‑term liquidity pressure, which may adversely affect SCE’s cash flows and liquidity position. For more information on liabilities related to wildfire events, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
Extreme heat events have and can continue to lead to prolonged widespread outages due to, among other things, state-wide capacity supply shortages or equipment failure. Extreme weather events can also lead to use of PSPS. Weather-related events, such as debris flows, flooding and melting of a significantly higher than normal snowpack, and earthquakes can cause over-topping or failure at an SCE dam resulting in a rapid release of water that could cause public safety issues, property damage and operational issues.
Weather-related incidents and other natural disasters can lead to lost revenue and increased costs, including higher maintenance and repair costs, which SCE may not be able to recover from its customers. These incidents can also result in
37
Table of Contents
regulatory penalties and disallowances, particularly if SCE encounters difficulties in restoring power to its customers on a timely basis or if fire-related losses are found to be the result of utility practices and/or the failure of electric and other utility equipment. In addition, these occurrences could lead to significant claims for damages, including for loss of life and property damage. These occurrences could materially affect SCE's business, financial condition and results of operations, and the inability to restore power to SCE's customers could also materially damage the business reputation of SCE and Edison International.
For additional information related to climate related risks, see "Business—Environmental Considerations—Environmental Risks."
The generation, transmission and distribution of electricity are dangerous and involve inherent risks of damage to private property and injury to SCE's workforce and the general public.
Electricity poses hazards for SCE's workforce and the general public should they come in contact with electrical current or equipment, including through energized downed power lines or if equipment malfunctions. In addition, the risks associated with the operation of transmission and distribution assets and power generation and storage facilities include public and workforce safety issues and the risk of utility assets causing or contributing to wildfires.
Injuries and property damage caused by such events can subject SCE to liability that, despite the existence of insurance coverage, can be significant. In addition, SCE may be held responsible for the actions of its contractors and from time to time, SCE is named as a party in legal proceedings involving claims related to its contractors and their employees. No assurance can be given that future losses will not exceed the limits of SCE's or its contractors' insurance coverage. Litigation and other legal processes are subject to inherent uncertainties, including, costs of litigation, unpredictable court or jury decisions, and the differing laws and sentiments regarding damage awards in regions where SCE operates.
The CPUC has increased its focus on public safety with an emphasis on heightened compliance with construction and operating standards and the potential for penalties being imposed on utilities. Additionally, the CPUC has delegated to its staff the authority to issue citations to electric utilities, which can impose fines of up to $100,000 per violation per day (capped at a maximum of $8 million), pursuant to the CPUC's jurisdiction for violations of safety rules found in statutes, regulations, and the CPUC's General Orders. The CPUC also can issue fines greater than $8 million outside of the citation program. Such penalties and liabilities could be significant and materially affect SCE's liquidity and results of operations.
SCE's financial condition and results of operations could be materially affected if it is unable to successfully manage the risks inherent in constructing, operating, and maintaining its facilities and workforce.
SCE's infrastructure is aging and could pose a risk to system reliability if not sufficiently maintained and expanded to meet load growth and electrification needs. In addition, as described above, natural disasters such as wildfires in SCE's service area can cause significant public safety issues, property damage and operational issues. SCE is engaged in a significant and ongoing infrastructure investment program. This investment program, which includes transmission projects and constructing utility owned storage to mitigate possible state-wide capacity shortages, has inherent operational risks and elevates the need for effective execution in SCE's activities. For example, utility owned storage facilities utilize lithium-ion battery technology that in certain circumstances can and have caused a thermal event that can ignite nearby materials, including other lithium-ion cells particularly when deployed in indoor facilities. SCE's financial condition and results of operations could be materially affected if it is unable to successfully manage these risks as well as the risks inherent in constructing, operating, and maintaining its facilities, the operation of which can be hazardous and important for system reliability. SCE's inherent operating risks include such matters as the risks of human performance; availability of skilled workforce and workforce capabilities; contractor management; data and records accuracy; public opposition to infrastructure projects; delays; environmental remediation and mitigation costs; difficulty in estimating costs or in recovering costs that are above original estimates; system limitations and degradation; unexpected cascading critical system failure; maintaining physical security of workforce and assets; maintaining cybersecurity of data and assets; and delays and interruptions in necessary supplies. For example, SCE's financial condition may be materially affected as a result of safety incidents, delays, permitting violations and violations of regulatory requirements, among other things, caused by SCE's failure to appropriately manage its contractor workforce or from contractual violations by SCE's contractors and the inability for SCE to recover through contractual indemnities or insurance held by the contractor. SCE's financial condition may also be materially affected as a result of data or records inaccuracies, for example, inaccurate records could lead to missing or delayed compliance with SCE's policies and regulatory requirements, and could contribute to safety incidents.
SCE's financial condition and results of operations could also be materially affected if SCE is unable to attract, train and retain a qualified workforce, and provide safe working conditions for its workforce, including its operations and management personnel. Constrained labor market in California and nationally and SCE's relations with its unionized workforce also impact SCE's ability to maintain its workforce. For example, the increased electrification efforts in California and nationally have led to greater competition for certain skilled workers.
38
Table of Contents
There are inherent risks associated with owning and decommissioning nuclear power generation facilities and obtaining cost reimbursement, including, among other things, insufficiency of nuclear decommissioning trust funds, costs exceeding current estimates, execution risks, potential harmful effects on the environment and human health and the hazards of storage, handling and disposal of radioactive materials. Existing insurance and ratemaking arrangements may not protect SCE fully against losses from a nuclear incident.
SCE funds decommissioning costs with assets that are currently held in nuclear decommissioning trusts. Based upon the financial performance of the nuclear decommissioning trust fund investments, as well as the resolution of a number of other uncertainties, assumptions and estimates, additional contributions to the nuclear decommissioning trust's funds may be required. If additional contributions to the nuclear decommissioning trust funds become necessary, recovery of any such additional funds through electric rates is subject to the CPUC's review and approval.
The costs of decommissioning San Onofre are subject to reasonableness reviews by the CPUC. These costs may not be recoverable through regulatory processes or otherwise unless SCE can establish that the costs were reasonably incurred. In addition, SCE faces inherent execution risks including such matters as the risks of human performance, workforce capabilities, public opposition, permitting delays, governmental approvals, and force majeure events. Decommissioning costs ultimately incurred could exceed the current estimates and cost increases resulting from contractual disputes, delays in performance by DGC, elevated levels of inflation, permitting delays, or force majeure events, among other things, could cause SCE to materially overrun current decommissioning cost estimates and could materially impact the sufficiency of trust funds. See "Liquidity and Capital Resources—SCE—Decommissioning of San Onofre" in the MD&A.
Even though San Onofre is being decommissioned, the presence of spent nuclear fuel still poses a potential risk of a nuclear incident. Federal law limits public liability claims from a nuclear incident to the amount of available financial protection, which is currently approximately $16.3 billion for Palo Verde and $560 million for San Onofre. SCE and other owners of San Onofre and Palo Verde have purchased the maximum private primary insurance available of $500 million per site. In the case of San Onofre, the balance is covered by a U.S. Government indemnity. In the case of Palo Verde, the balance is covered by a loss sharing program among nuclear reactor licensees. There is no assurance that the CPUC would allow SCE to recover the required contribution made pursuant to this loss sharing program in the case of one or more nuclear incidents with claims that exceeded $500 million at a nuclear reactor which is participating in the program. If this public liability limit of $16.3 billion is insufficient, federal law contemplates that additional funds may be appropriated by Congress. There can be no assurance of SCE's ability to recover uninsured costs in the event the additional federal appropriations are insufficient. For more information on nuclear insurance risk, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Nuclear Insurance."
SCE's distribution of water and propane gas on Catalina Island involves inherent risks of damage to private property and the environment and injury to employees and the general public.
SCE owns and operates the water distribution system that serves Catalina Island, California and a propane gas distribution system that serves the City of Avalon on the island. Production, storage, treatment and distribution of water for human use and the transportation, storage, distribution and use of gas can be hazardous, and can cause damage to private property and the environment and injury to employees and the general public if equipment fails or does not perform as anticipated. For example, the risks of operating a water distribution system include the potential for burst pipes and water contamination and the risks of operating gas distribution system include the potential for gas leaks, fire or explosion. The risks related to SCE's operation of its water and gas distribution systems may be exacerbated due to aging infrastructure. SCE has, in the past, requested that the CPUC allow SCE to include certain water system costs in electric rates and may make similar requests for the water and gas systems in the future. If such requests are denied, significant costs may not be recoverable from customers. In addition, SCE may have to pay fines, penalties and remediation costs if it does not comply with laws and regulations in the operation of the water and gas distribution systems. An inability to recover costs associated with any such damages or injuries or any fines, penalties or remediation costs, from insurance or through electric rates, could materially affect SCE's business, financial condition and results of operations.
Financing Risks
As a capital-intensive company, SCE relies on access to the bank and capital markets. If SCE were unable to access these markets or the cost of financing were to substantially increase, its liquidity and operations could be materially affected.
SCE regularly accesses the bank and capital markets to finance its activities and is expected to do so by its regulators as part of its obligation to serve its customers. SCE needs substantial capital for its ongoing infrastructure investment program and for financing wildfire related losses. SCE's ability to obtain financing, as well as its ability to refinance debt and make scheduled payments of principal and interest, are dependent on numerous factors, including SCE's levels of indebtedness, maintenance of acceptable credit ratings, financial performance, liquidity and cash flow, increases in interest rates and credit spreads due to inflationary pressures, and other market conditions. In addition, the actions of other California
39
Table of Contents
investor-owned utilities and legal, regulatory and legislative decisions impacting investor-owned utilities can affect market conditions and therefore, SCE's ability to obtain financing. SCE's inability to obtain additional capital from time to time could have a material effect on SCE's liquidity and operations.
Competitive and Market Risks
If SCE is unable to operate efficiently and to effectively and timely respond to the changes that the electricity industry is undergoing, as a result of increased load requirements, competition, technological advances, and changes to the regulatory environment, SCE's business model, financial condition and results of operations could be materially impacted.
SCE’s ability to efficiently operate and implement process changes has a direct impact on its ability to execute its strategy, its customer rates and affordability of electricity. Even if SCE’s costs are recoverable, the necessary costs of operations and investments supporting safety, reliability, resilience and being ready to meet California’s clean energy goals will negatively impact the affordability of SCE’s customer rates, may cause reputational harm and cause increased load departures.
Customers and third parties are increasingly deploying DERs, such as solar generation, energy storage, energy efficiency and demand response technologies. California's environmental policy objectives are accelerating the pace and scope of industry change. This change will require modernization of the electric distribution grid to, among other things, accommodate two-way flows of electricity and increase the grid's capacity to interconnect DERs. In addition, enabling California's clean energy economy goals will require sustained investments in grid modernization, renewable integration projects, energy efficiency programs, energy storage options and electric vehicle infrastructure. If SCE is unable to operate efficiently and adapt to these changes, its business model, its ability to execute on its strategy, and ultimately its financial condition and results of operations could be materially impacted.
Customer-owned generation and load departures to CCAs or Electric Service Providers each reduce the amount of electricity that customers purchase from utilities and have the effect of increasing utility rates unless customer rates are designed to allocate the costs of the distribution grid across all customers that benefit from its use. For example, some customers in California who generate their own power are not currently required to pay all transmission and distribution charges and non-bypassable charges, subject to limitations, which results in increased costs for other customers. If there are no updates in regulations to further support the need for customers to pay their share of transmission and distribution costs and non-bypassable charges, and the demand for electricity reduces so significantly that SCE is no longer effectively able to recover such costs from its customers, SCE's business, financial condition and results of operations will be materially impacted.
In addition, the FERC has opened transmission development to competition from independent developers, allowing such developers to compete with incumbent utilities for the construction and operation of transmission facilities.
For more information. See "Business—SCE—Competition."
RISKS RELATING TO EDISON INTERNATIONAL AND SOUTHERN CALIFORNIA EDISON COMPANY
Cybersecurity and Physical Security Risks
Successful attacks on SCE information and operational technology systems and infrastructure could have a material impact on SCE's operations or financial condition
Edison International and SCE systems, assets and personnel are targets for physical and cyber attacks. Regulators such as NERC and U.S. Government agencies, including the Departments of Defense, Homeland Security, and Energy, have increasingly stressed that threat sources, including nation-state actors, continue to seek to identify and exploit vulnerabilities in the U.S. national electric grid and other critical energy infrastructures, and that such attacks and disruptions, both physical and cyber, are highly sophisticated and dynamic. Several U.S. Government agencies have highlighted the increasing risks related to physical and cybersecurity attacks, including ransomware attacks, related to the electric sector, including its supply chain, and that the risks may escalate during periods of heightened geopolitical tensions.
SCE requires the uninterrupted use of sophisticated information and operational technology systems and infrastructure to monitor and operate the electric grid. In the regular course of SCE’s business, it also handles a range of sensitive infrastructure, security, employee, customer, and business systems information. If SCE's information technology and operational technology systems' security were to be compromised by physical or electronic means or a critical system or technology failure were to occur without timely recovery, including failure of new technology to be implemented as designed, SCE could be unable to fulfill critical business functions and/or sensitive information could be misappropriated or compromised. Such events could result in violations of privacy and other laws, material financial loss to SCE and/or to its customers, loss of confidence in SCE's security risk management, customer dissatisfaction, and significant litigation
40
Table of Contents
and/or regulatory exposure, all of which could materially affect Edison International’s and SCE's financial condition, operations, and the business reputation of Edison International and SCE.
SCE's security program cannot prevent all attacks or incidents
SCE's systems have experienced, and will continue to face, cyber and physical security events involving malicious code, unauthorized access attempts, vandalism and other illicit activities. No security program can completely shield its systems, infrastructure, and data from attacks, intrusions, or other catastrophic events that could result in their failure or reduced functionality. There is no guarantee that SCE's security program, including prevention, detection, mitigation, and remediation of risks, will prevent all future cyber and physical security incidents that could materially impact its operations or financial condition.
SCE is not able to anticipate and prevent all physical and cyber attacks or information security breaches, and its investments in security resources, talent, and business practices may not be effective against all threat actors, particularly nation-state actors. Voluntary cybersecurity guidelines and practices cannot be applied to all businesses equally due to system capability, complexity, and resources for implementation. SCE's security tools and controls, including those supporting configuration management, identity and access management, network segmentation, and boundary defenses, may not fully protect against unauthorized access from internal and external threats. SCE's current security controls and defenses may also not protect against insider threats, including deliberate and unintentional actions (e.g., human error) and other emerging cybersecurity risks created by artificial intelligence, quantum computing, cyber skills shortages, and regulatory constraints.
SCE's security program is prioritized based on known risks, available resources, and regulatory requirements, and therefore all SCE assets are not equally protected. For example, not all of SCE's information technology assets are inventoried, which could result in unmitigated vulnerabilities or slow the detection, investigation, and recovery of an incident. Known vulnerabilities in SCE's information technology and operational technology environments may not be remediated before an adversary could discover or exploit them. Attackers can also exploit new, unknown vulnerabilities (e.g., zero day) and vulnerabilities where a patch or other remediation measure is not yet available.
SCE's transition to a more network-connected grid and increased deployment of new technologies increases the number of systems adversaries can target
SCE's operations require the continuous availability and deployment of critical information and operational technology systems, sensitive customer and employee data and infrastructure information, all of which are targets for malicious actors. New cyber and physical threats arise as SCE moves to an increasingly digital electric grid. For example, SCE's grid modernization efforts and the transition to a more connected grid, including the integration of new technologies and increased networking of operational technology assets such as substations, increases the threat surface and potential vulnerabilities that an adversary can target. As new systems are developed or procured by SCE, software development practices may not comprehensively prevent the introduction of new software vulnerabilities. Additionally, certain existing or legacy information technology, operational technology, and communications infrastructure use less secure protocols or configurations.
Vendors and other third parties may be used to target and attack SCE
SCE interacts with a wide array of third parties and depends on vendors to provide it with products and services. These products and services may contain vulnerabilities and could require patching which could cause disruptions to SCE's operations. Malicious actors may attack vendors to disrupt the services they provide to SCE, or to use those vendors as a conduit to attack SCE. SCE system data and architecture are also disclosed, either voluntarily or by mandate, to third parties and the public by regulators, employees, contractors, and vendors. This system data may be used by malicious actors to understand SCE’s systems to prepare for a cyber or physical attack.
The products and services provided by SCE's vendors may contain vulnerabilities or otherwise not adhere to SCE's enterprise cybersecurity standards (e.g., lack of encryption). Additionally, SCE's operational technology vendors have increasingly been targeted by threat actors. A compromise of equipment and/or exfiltration of SCE data, whether by physical or by electronic means, could result in loss or changes to confidential or sensitive information and interruption of business processes. For example, compromises to widely-used products and services may affect the supply chains of many industries, including companies in SCE’s supply chain. While SCE vendors have experienced cybersecurity incidents, such incidents have not, to SCE's knowledge, resulted in a material impact to SCE to date.
41
Table of Contents
Global and Regional Risks
Edison International's and SCE's financial condition and results of operations could be materially impacted by catastrophic, macroeconomic and geopolitical events that cause significant disruption to workforces, supply chains, economies, or societies on a regional, statewide, national or global basis.
Edison International and SCE could be materially and adversely impacted by catastrophic, macroeconomic and geopolitical events, such as the effects of increased inflationary pressures and interest rates, potential economic downturns or recessions, geopolitical pressures, and pandemics and regional health emergencies. For example, the global spread of COVID-19, which was declared a pandemic by the World Health Organization in March 2020, created significant uncertainty, volatility and disruption globally that resulted in, among other things, disruption to supply chains, economies, and workforce and impacted the operations of Edison International and SCE. Additionally, the geopolitical developments involving the Russia-Ukraine conflict, China and the Middle East, could cause delays and disruptions in the supply chain and the availability and timely delivery of services, materials and components used in SCE’s operations. Geopolitical tensions can also heighten cybersecurity risks, including the risk of malicious activity by state‑sponsored actors. For additional information regarding these cybersecurity threats, see “—Cybersecurity and Physical Security Risks.” Evolving U.S. and California governmental policies and regulatory initiatives could lead to changes in economic conditions or economic uncertainties in the State of California, United States and globally, including impacts to infrastructure investments, tariffs, taxes, and energy, environmental and social policies.
Many of the risks and uncertainties identified in this Form 10-K have, and will be, exacerbated by the impacts of a catastrophic event and the actions taken by governmental entities, businesses, individuals and others in response to such an event. In addition, impacts of international conflict, recession, pandemic or similar events on SCE's customers and third parties could also result in SCE facing, among other things, significant reductions in demand for electricity and payment delays and/or defaults from customers which could result in significant under-collections. Edison International and SCE access to the bank and capital markets and/or the costs of accessing those markets could be constrained and could also face payment delays and/or defaults from insurers and other counterparties. These impacts, among others, could materially and adversely impact Edison International's and SCE's business, operations, cash flows, liquidity and financial results.
Edison International's and SCE's business activities are concentrated in one industry and in one region.
Substantially all of Edison International's and all of SCE's business activities are concentrated in the electric utility industry. Edison International's principal subsidiary, SCE, serves customers only in southern and central California. As a result, Edison International's and SCE's future performance may be affected by events and economic factors unique to California or by regional regulation, legislation or judicial decisions. For example, California courts have applied strict liability to investor-owned utilities in wildfire and other litigation matters. See "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Information responding to this section is included in the MD&A under the heading "Market Risk Exposures."
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
42
Table of Contents
Report of Independent Registered Public Accounting Firm
To the Board of Directors and Shareholders of Edison International
Opinions on the Financial Statements and Internal Control Over Financial Reporting
We have audited the accompanying consolidated balance sheets of Edison International and its subsidiaries (the "Company") as of December 31, 2025 and 2024, and the related consolidated statements of income, of comprehensive income, of changes in equity and of cash flows for each of the three years in the period ended December 31, 2025, including the related notes and schedule of condensed financial information of parent as of December 31, 2025 and 2024 and for each of the three years in the period ended December 31, 2025 appearing after Item 15(a)(3) (collectively referred to as the "consolidated financial statements"). We also have audited the Company's internal control over financial reporting as of December 31, 2025, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2025 and 2024, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2025 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2025, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.
Basis for Opinions
The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in Management’s Report on Internal Control Over Financial Reporting appearing under Item 9A. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (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 audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
43
Table of Contents
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that (i) relate to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Southern California Wildfires Loss Contingencies – 2025 Eaton Fire
As described in Note 12 to the consolidated financial statements, in January 2025, several wind-driven wildfires impacted portions of Southern California Edison Company’s (SCE) service area, causing loss of life, substantial damage to both residential and business properties, and service outages for SCE customers. One of the largest of these wildfires, the "Eaton Fire," ignited in SCE's service area in Los Angeles County and spread due to a number of contributing factors under conditions of an extreme Santa Ana windstorm. Each reporting period, management reviews the Company’s loss estimates for remaining alleged and potential claims related to wildfire events. The process for estimating losses associated with alleged and potential wildfire related claims requires management to exercise significant judgment based on a number of assumptions and subjective factors, including, but not limited to: volumes of claims, damages asserted and associated loss, opinions of counsel regarding litigation risk, the status of and developments in the course of litigation, prior experience litigating and settling wildfire litigation claims, the amount of insurance that may offset losses, and estimating contributory liabilities from third parties who may be responsible for portions of loss. As additional information becomes available, management's estimates and assumptions regarding the causes and financial impact of wildfire events may change. In light of pending litigation, it is probable that the Company will incur additional material losses in connection with the Eaton Fire; however, the Company is currently unable to reasonably estimate a range of losses that may be incurred.
The principal considerations for our determination that performing procedures relating to the Southern California Wildfires Loss Contingencies - 2025 Eaton Fire is a critical audit matter are (i) the significant judgment by management when determining whether a loss is probable and when determining whether the amount of the loss or range of loss can be reasonably estimated as it relates to the 2025 Eaton Fire and (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management's assessment of the loss contingencies associated with the 2025 Eaton Fire.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management's assessment of the loss contingencies associated with the 2025 Eaton Fire, including controls over assessing whether a loss is probable and whether the amount of the loss or range of loss can be reasonably estimated based on currently available information, as well as financial statement disclosures. These procedures also included, among others (i) obtaining and evaluating the letters of audit inquiry with internal and external legal counsel, (ii) evaluating, on a sample basis, contracts and agreements for executed settlements, (iii) evaluating the reasonableness of management’s assessment regarding whether an unfavorable outcome is reasonably possible or probable and reasonably estimable; and (iv) evaluating the sufficiency of the Company’s disclosures related to the 2025 Eaton Fire.
Accounting for the Effects of Rate Regulation
As described in Notes 1 and 11 to the consolidated financial statements, the Company's accounting policies conform to accounting principles generally accepted in the United States of America, including the accounting principles for rate-regulated enterprises, which reflect the ratemaking policies of the California Public Utility Commission (CPUC) and the FERC. Management applies authoritative guidance for rate-regulated enterprises to the portion of the Company’s operations in which regulators set rates at levels intended to recover the estimated costs of providing service, plus a return on net investments in assets, or rate base. Regulators may also impose certain penalties or grant certain incentives. Due to timing and other differences in the collection of electric utility revenue, these accounting principles require an incurred cost that would otherwise be charged to expense by a non-regulated entity to be capitalized as a regulatory asset if it is probable that the cost is recoverable through future rates; and conversely the accounting principles require recording of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. As disclosed by management, management assesses at the end of each reporting period whether regulatory assets are probable of future recovery by considering factors such as the current regulatory environment, the issuance of rate orders on recovery of the specific or a similar incurred cost to the Company or other rate-regulated entities, and other factors that would indicate that the regulator will treat an incurred cost as allowable for ratemaking purposes. As of December 31, 2025, $16.3 billion was recorded in regulatory assets and $11.8 billion was recorded in regulatory liabilities.
44
Table of Contents
The principal considerations for our determination that performing procedures relating to accounting for the effects of rate regulation is a critical audit matter are a high degree of auditor effort in performing procedures and evaluating audit evidence related to management’s assessment of the recoverability and settlement of existing and new regulatory assets and liabilities.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to the Company's regulatory accounting process, including controls over management’s assessment of the recoverability and settlement of existing and new regulatory assets and liabilities. These procedures also included, among others (i) obtaining and evaluating the Company's correspondence with regulators; (ii) evaluating the reasonableness of management's assessment regarding the probability of recovery of regulatory assets and settlement of regulatory liabilities at the balance sheet date; (iii) evaluating the sufficiency of the disclosures; and (iv) testing, on a sample basis, the calculation of regulatory assets and regulatory liabilities based on provisions outlined in the rate orders.

/s/PricewaterhouseCoopers LLP
Los Angeles, California
February 18, 2026
We have served as the Company’s auditor since 2002.
45
Table of Contents
Report of Independent Registered Public Accounting Firm
To the Board of Directors and Shareholders of Southern California Edison Company
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Southern California Edison Company and its subsidiaries (the "Company") as of December 31, 2025 and 2024, and the related consolidated statements of income, of comprehensive income, of changes in equity and of cash flows for each of the three years in the period ended December 31, 2025, including the related notes (collectively referred to as the "consolidated financial statements"). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2025 and 2024, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2025 in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (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 audits of these consolidated financial statements in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that (i) relate to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Southern California Wildfires Loss Contingencies – 2025 Eaton Fire
As described in Note 12 to the consolidated financial statements, in January 2025, several wind-driven wildfires impacted portions of Southern California Edison Company’s (SCE) service area, causing loss of life, substantial damage to both residential and business properties, and service outages for SCE customers. One of the largest of these wildfires, the "Eaton Fire," ignited in SCE's service area in Los Angeles County and spread due to a number of contributing factors under conditions of an extreme Santa Ana windstorm. Each reporting period, management reviews the Company’s loss estimates for remaining alleged and potential claims related to wildfire events. The process for estimating losses associated with alleged and potential wildfire related claims requires management to exercise significant judgment based on a number of assumptions and subjective factors, including, but not limited to: volumes of claims, damages asserted and associated loss, opinions of counsel regarding litigation risk, the status of and developments in the course of litigation, prior experience litigating and settling wildfire litigation claims, the amount of insurance that may offset losses, and estimating contributory liabilities from third parties who may be responsible for portions of loss. As additional information becomes available, management's estimates and assumptions regarding the causes and financial impact of wildfire events may change. In light of pending litigation, it is probable that the Company will incur additional material losses in connection with the Eaton Fire; however, the Company is currently unable to reasonably estimate a range of losses that may be incurred.
46
Table of Contents
The principal considerations for our determination that performing procedures relating to the Southern California Wildfires Loss Contingencies - 2025 Eaton Fire is a critical audit matter are (i) the significant judgment by management when determining whether a loss is probable and when determining whether the amount of the loss or range of loss can be reasonably estimated as it relates to the 2025 Eaton Fire and (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management's assessment of the loss contingencies associated with the 2025 Eaton Fire.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management's assessment of the loss contingencies associated with the 2025 Eaton Fire, including controls over assessing whether a loss is probable and whether the amount of the loss or range of loss can be reasonably estimated based on currently available information, as well as financial statement disclosures. These procedures also included, among others (i) obtaining and evaluating the letters of audit inquiry with internal and external legal counsel, (ii) evaluating, on a sample basis, contracts and agreements for executed settlements, (iii) evaluating the reasonableness of management’s assessment regarding whether an unfavorable outcome is reasonably possible or probable and reasonably estimable; and (iv) evaluating the sufficiency of the Company’s disclosures related to the 2025 Eaton Fire.
Accounting for the Effects of Rate Regulation
As described in Notes 1 and 11 to the consolidated financial statements, the Company's accounting policies conform to accounting principles generally accepted in the United States of America, including the accounting principles for rate-regulated enterprises, which reflect the ratemaking policies of the California Public Utility Commission (CPUC) and the FERC. Management applies authoritative guidance for rate-regulated enterprises to the portion of the Company’s operations in which regulators set rates at levels intended to recover the estimated costs of providing service, plus a return on net investments in assets, or rate base. Regulators may also impose certain penalties or grant certain incentives. Due to timing and other differences in the collection of electric utility revenue, these accounting principles require an incurred cost that would otherwise be charged to expense by a non-regulated entity to be capitalized as a regulatory asset if it is probable that the cost is recoverable through future rates; and conversely the accounting principles require recording of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. As disclosed by management, management assesses at the end of each reporting period whether regulatory assets are probable of future recovery by considering factors such as the current regulatory environment, the issuance of rate orders on recovery of the specific or a similar incurred cost to the Company or other rate-regulated entities, and other factors that would indicate that the regulator will treat an incurred cost as allowable for ratemaking purposes. As of December 31, 2025, $16.3 billion was recorded in regulatory assets and $11.8 billion was recorded in regulatory liabilities.
The principal considerations for our determination that performing procedures relating to accounting for the effects of rate regulation is a critical audit matter are a high degree of auditor effort in performing procedures and evaluating audit evidence related to management’s assessment of the recoverability and settlement of existing and new regulatory assets and liabilities.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to the Company's regulatory accounting process, including controls over management’s assessment of the recoverability and settlement of existing and new regulatory assets and liabilities. These procedures also included, among others (i) obtaining and evaluating the Company's correspondence with regulators; (ii) evaluating the reasonableness of management's assessment regarding the probability of recovery of regulatory assets and settlement of regulatory liabilities at the balance sheet date; (iii) evaluating the sufficiency of the disclosures; and (iv) testing, on a sample basis, the calculation of regulatory assets and regulatory liabilities based on provisions outlined in the rate orders.


/s/PricewaterhouseCoopers LLP
Los Angeles, California
February 18, 2026
We have served as the Company’s auditor since 2002.
47
Table of Contents
CONSOLIDATED FINANCIAL STATEMENTS
Consolidated Statements of IncomeEdison International
Years ended December 31,
(in millions, except per-share amounts)202520242023
Operating revenue$19,317 $17,599 $16,338 
Purchased power and fuel4,933 5,209 5,486 
Operation and maintenance5,098 5,172 4,138 
Wildfire-related claims, net of (recoveries)(1,959)652 667 
Wildfire Fund expense144 146 213 
Depreciation and amortization3,237 2,866 2,635 
Property and other taxes665 624 571 
Asset impairment106 — 1 
Total operating expenses12,224 14,669 13,711 
Operating income7,093 2,930 2,627 
Interest expense(1,539)(1,869)(1,612)
Other income, net438 502 500 
Income before income taxes5,992 1,563 1,515 
Income tax expense1,291 17 108 
Net income4,701 1,546 1,407 
Less: Preference stock dividend requirements of SCE144 175 123 
Preferred stock dividend requirements of Edison International98 87 87 
Net income available to Edison International common shareholders4,459 1,284 1,197 
Basic earnings per share:
Weighted average shares of common stock outstanding385386383
Basic earnings per common share available to Edison International common shareholders$11.58$3.33$3.12
Diluted earnings per share:
Weighted average shares of common stock outstanding, including effect of dilutive securities386388385
Diluted earnings per common share available to Edison International common shareholders$11.55$3.31$3.11
The accompanying notes are an integral part of these consolidated financial statements.
48
Table of Contents
Consolidated Statements of Comprehensive IncomeEdison International
Years ended December 31,
(in millions)202520242023
Net income$4,701 $1,546 $1,407 
Other comprehensive income (loss), net of tax:
Pension and postretirement benefits other than pensions5 9 (1)
Foreign currency translation adjustments1 — 3 
Other comprehensive income, net of tax6 9 2 
Comprehensive income4,707 1,555 1,409 
Less: Comprehensive income attributable to noncontrolling interests144 175 123 
Comprehensive income attributable to Edison International$4,563 $1,380 $1,286 
The accompanying notes are an integral part of these consolidated financial statements.
49
Table of Contents
Consolidated Balance SheetsEdison International
December 31,
(in millions)20252024
ASSETS
Cash and cash equivalents$158 $193 
Receivables, net of allowances for uncollectible accounts of $356 and $352 at respective dates
1,463 2,169 
Accrued unbilled revenue1,238 848 
Inventory535 538 
Prepaid expenses119 103 
Regulatory assets3,290 2,748 
Wildfire Fund contributions138 138 
Other current assets745 418 
Total current assets7,686 7,155 
Nuclear decommissioning trusts4,535 4,286 
Other investments51 57 
Total investments4,586 4,343 
Utility property, plant and equipment, net of accumulated depreciation and amortization of $15,060 and $14,207 at respective dates
63,131 59,047 
Nonutility property, plant and equipment, net of accumulated depreciation of $132 and $124 at respective dates
197 207 
Total property, plant and equipment63,328 59,254 
Receivables, net of allowances for uncollectible accounts of $49 and $43 at respective dates
38 62 
Regulatory assets (include $3,092 and $1,512 related to a Variable Interest Entity ("VIE") at respective dates)
12,960 8,886 
Wildfire Fund contributions1,740 1,878 
Operating lease right-of-use assets1,161 1,180 
Long-term insurance receivables359 418 
Other long-term assets2,168 2,403 
Total other assets18,426 14,827 
Total assets$94,026 $85,579 
The accompanying notes are an integral part of these consolidated financial statements.
50
Table of Contents
Consolidated Balance SheetsEdison International
December 31,
(in millions, except share amounts)20252024
LIABILITIES AND EQUITY
Short-term debt$2,390 $998 
Current portion of long-term debt1,928 2,049 
Accounts payable2,344 2,000 
Wildfire-related claims585 60 
Accrued interest473 422 
Regulatory liabilities1,158 1,347 
Current portion of operating lease liabilities120 124 
Other current liabilities1,538 1,439 
Total current liabilities10,536 8,439 
Long-term debt (includes $3,022 and $1,468 related to a VIE at respective dates)
36,070 33,534 
Deferred income taxes and credits9,114 7,180 
Pensions and benefits370 384 
Asset retirement obligations2,583 2,580 
Regulatory liabilities10,627 10,159 
Operating lease liabilities1,041 1,056 
Wildfire-related claims721 941 
Other deferred credits and other long-term liabilities3,705 3,566 
Total deferred credits and other liabilities28,161 25,866 
Total liabilities74,767 67,839 
Commitments and contingencies (Note 12)
Preferred stock (50,000,000 shares authorized; 414,342 and 1,159,317 shares of Series A and 87,937 and 503,454 shares of Series B issued and outstanding at respective dates)
497 1,645 
Common stock, no par value (800,000,000 shares authorized; 384,787,056 and 384,784,719 shares issued and outstanding at respective dates)
6,362 6,353 
Accumulated other comprehensive income6 — 
Retained earnings10,714 7,567 
Total Edison International's shareholders' equity17,579 15,565 
Noncontrolling interests – preference stock of SCE1,680 2,175 
Total equity19,259 17,740 
Total liabilities and equity$94,026 $85,579 
The accompanying notes are an integral part of these consolidated financial statements.
51
Table of Contents
Consolidated Statements of Cash FlowsEdison International
Years ended December 31,
(in millions)202520242023
Cash flows from operating activities:
Net income$4,701 $1,546 $1,407 
Adjustments to reconcile to net cash provided by operating activities:
Depreciation and amortization3,237 2,866 2,635 
Equity allowance for funds used during construction(189)(187)(157)
Asset impairment 106 — 1 
Deferred income taxes1,208 9 108 
Wildfire Fund amortization expense144 146 213 
Other176 154 143 
Nuclear decommissioning trusts(123)(174)(180)
Contributions to Wildfire Fund(95)(95)(95)
Changes in operating assets and liabilities:
Receivables662 (278)(349)
Inventory(4)(14)(63)
Accounts payable78 53 (408)
Other current assets and liabilities(253)(85)194 
Derivative assets and liabilities, net(11)28 (174)
Regulatory assets and liabilities, net(3,445)1,219 576 
Wildfire-related claims, net of insurance recoveries(610)(314)(446)
Other noncurrent assets and liabilities218 140 (4)
Net cash provided by operating activities5,800 5,014 3,401 
Cash flows from financing activities:
Long-term debt issued, net of discount and issuance costs of $60, $44, and $54 for the respective years
5,133 5,256 5,121 
Long-term debt repaid(2,052)(2,701)(2,498)
Short-term debt issued1,260 — 1,076 
Short-term debt repaid(230)(401)(2,407)
Common stock repurchased(32)(200)— 
Preferred and preference stock issued, net of issuance cost— 345 542 
Preferred and preference stock repurchased and redeemed(1,664)(656)(289)
Commercial paper (repayments) borrowing, net(346)308 1,102 
Dividends and distribution to noncontrolling interests(136)(168)(117)
Common stock dividends paid(1,274)(1,198)(1,112)
Preferred stock dividends paid(104)(88)(108)
Other16 177 137 
Net cash provided by financing activities571 674 1,447 
Cash flows from investing activities:
Capital expenditures(6,515)(5,707)(5,448)
Proceeds from sale of nuclear decommissioning trust investments6,219 5,019 4,597 
Purchases of nuclear decommissioning trust investments(6,098)(4,898)(4,417)
Other59 50 35 
Net cash used in investing activities(6,335)(5,536)(5,233)
Net increase (decrease) in cash and cash equivalents and restricted cash and cash equivalents36 152 (385)
Cash and cash equivalents and restricted cash and cash equivalents at beginning of year684 532 917 
Cash and cash equivalents and restricted cash and cash equivalents at end of year$720 $684 $532 
The accompanying notes are an integral part of these consolidated financial statements.
52
Table of Contents
Consolidated Statements of Changes in EquityEdison International
Equity Attributable to Edison International ShareholdersNoncontrolling
Interests
Preferred stock
Common stock
Accumulated
Other
Comprehensive
(Loss) Income		Retained
Earnings		SubtotalPreference
Stock		Total
Equity
(in millions, except shares and per share amounts)
Shares
Amount
Shares
Amount
Balance at December 31, 20222,000,000 $1,978 382,208,498 $6,200 $(11)$7,454 $15,621 $1,901 $17,522 
Net income— — — — — 1,284 1,284 123 1,407 
Other comprehensive income— — — — 2 — 2 — 2 
Common stock issued— — 1,716,414 92 — — 92 — 92 
Common stock dividends declared ($2.9925 per share)
— — — — — (1,147)(1,147)— (1,147)
Preferred stock dividend accrued ($53.75 per share for Series A and $50 per share for Series B)
— — — — — (108)(108)— (108)
Dividends to noncontrolling interests ($96.8230 - $143.75 per share for preference stock)
— — — — — — — (123)(123)
Noncash stock-based compensation— — — 46 — — 46 — 46 
Preference stock issued, net of issuance cost
———————542542 
Preferred stock repurchased
(308,229)(305)———16(289)—(289)
Balance at December 31, 20231,691,771 1,673 383,924,912 6,338 (9)7,499 15,501 2,443 17,944 
Net income— — — — — 1,371 1,371 175 1,546 
Other comprehensive income— — — — 9 — 9 — 9 
Common stock issued— — 3,272,010 158 — — 158 — 158 
Common stock repurchased— — (2,412,203)(200)— — (200)— (200)
Common stock dividends declared ($3.1675 per share)
— — — — — (1,221)(1,221)— (1,221)
Preferred stock dividend declared ($53.75 per share for Series A and $50.00 per share for Series B)
— — — — — (88)(88)— (88)
Dividends to noncontrolling interests ($24.418 - $199.479 per share for preference stock)
— — — — — 6 6 (160)(154)
Noncash stock-based compensation— — — 57 — — 57 — 57 
Preference stock issued, net of issuance cost— — — — — — — 345 345 
Preference stock redeemed
— — — — — — — (628)(628)
Preferred stock repurchased(29,000)(28)— — — — (28)— (28)
Balance at December 31, 20241,662,771 1,645 384,784,719 6,353 — 7,567 15,565 2,175 17,740 
Net income— — — — — 4,557 4,557 144 4,701 
Other comprehensive income— — — — 6 — 6 — 6 
Common stock issued— — 553,336 5 — — 5 — 5 
Common stock repurchased——(550,999)(32)—— (32)—(32)
Common stock dividends declared ($3.36 per share)
— — — — — (1,293)(1,293)— (1,293)
Preferred stock dividend declared ($53.75 per share for Series A and $50.00 per share for Series B)
— — — — — (104)(104)— (104)
Dividends to noncontrolling interests ($125 - $187.5 per share for preference stock)
— — — — — (1)(1)(135)(136)
Shares withheld for tax withholdings on vested equity awards
— — (21)— — (21)— (21)
Noncash stock-based compensation— — — 57 — — 57 — 57 
Preference stock redeemed and repurchased— — — — — — — (504)(504)
Preferred stock repurchased(1,160,492)(1,148)— — — (12)(1,160)— (1,160)
Balance at December 31, 2025502,279 $497 384,787,056 $6,362 $6 $10,714 $17,579 $1,680 $19,259 
The accompanying notes are an integral part of these consolidated financial statements.
53
Table of Contents










(This page has been left blank intentionally.)

54
Table of Contents
Consolidated Statements of IncomeSouthern California Edison Company
Years ended December 31,
(in millions)202520242023
Operating revenue$19,276 $17,547 $16,275 
Purchased power and fuel4,933 5,209 5,486 
Operation and maintenance4,999 5,064 4,071 
Wildfire-related claims, net of (recoveries)(2,009)647 665 
Wildfire Fund expense144 146 213 
Depreciation and amortization3,233 2,865 2,633 
Property and other taxes662 620 566 
Asset impairment106 — 1 
Total operating expenses12,068 14,551 13,635 
Operating income7,208 2,996 2,640 
Interest expense(1,207)(1,575)(1,356)
Other income, net447 493 497 
Income before income taxes6,448 1,914 1,781 
Income tax expense1,415 120 184 
Net income5,033 1,794 1,597 
Less: Preference stock dividend requirements144 175 123 
Net income available for common stock$4,889 $1,619 $1,474 
The accompanying notes are an integral part of these consolidated financial statements.


Consolidated Statements of Comprehensive Income
Southern California Edison Company
Years ended December 31,
(in millions)202520242023
Net income$5,033 $1,794 $1,597 
Other comprehensive (loss) income, net of tax:
Pension and postretirement benefits other than pensions(3)3 (4)
Other comprehensive (loss) income, net of tax(3)3 (4)
Comprehensive income$5,030 $1,797 $1,593 
The accompanying notes are an integral part of these consolidated financial statements.
55
Table of Contents
Consolidated Balance SheetsSouthern California Edison Company
December 31,
(in millions)20252024
ASSETS
Cash and cash equivalents$98 $78 
Receivables, net of allowances for uncollectible accounts of $353 and $347 at respective dates
1,455 2,160 
Accrued unbilled revenue1,236 845 
Inventory535 538 
Prepaid expenses118 102 
Regulatory assets3,290 2,748 
Wildfire Fund contributions138 138 
Other current assets743 415 
Total current assets7,613 7,024 
Nuclear decommissioning trusts4,535 4,286 
Other investments40 38 
Total investments4,575 4,324 
Utility property, plant and equipment, net of accumulated depreciation and amortization of $15,060 and $14,207 at respective dates
63,131 59,047 
Nonutility property, plant and equipment, net of accumulated depreciation of $113 and $108 at respective dates
188 199 
Total property, plant and equipment63,319 59,246 
Receivables, net of allowances for uncollectible accounts of $49 and $43 at respective dates
38 62 
Regulatory assets (include $3,092 and $1,512 related to a VIE at respective dates)
12,960 8,886 
Wildfire Fund contributions1,740 1,878 
Operating lease right-of-use assets1,155 1,174 
Long-term insurance receivables145 131 
Long-term insurance receivables due from affiliate226 303 
Other long-term assets2,074 2,317 
Total other assets18,338 14,751 
Total assets$93,845 $85,345 

The accompanying notes are an integral part of these consolidated financial statements.
56
Table of Contents
Consolidated Balance SheetsSouthern California Edison Company
December 31,
(in millions, except share amounts)20252024
LIABILITIES AND EQUITY
Short-term debt$1,036 $553 
Current portion of long-term debt1,928 1,249 
Accounts payable2,353 2,078 
Wildfire-related claims585 60 
Accrued interest432 385 
Regulatory liabilities1,158 1,347 
Current portion of operating lease liabilities118 123 
Other current liabilities1,599 1,495 
Total current liabilities9,209 7,290 
Long-term debt (includes $3,022 and $1,468 related to a VIE at respective dates)
31,255 29,266 
Deferred income taxes and credits10,712 8,697 
Pensions and benefits87 92 
Asset retirement obligations2,583 2,580 
Regulatory liabilities10,627 10,159 
Operating lease liabilities1,037 1,051 
Wildfire-related claims721 941 
Other deferred credits and other long-term liabilities3,684 3,518 
Total deferred credits and other liabilities29,451 27,038 
Total liabilities69,915 63,594 
Commitments and contingencies (Note 12)
Preference stock1,714 2,220 
Common stock, no par value (560,000,000 shares authorized; 434,888,104 shares issued and outstanding at respective dates)
2,168 2,168 
Additional paid-in capital8,970 8,950 
Accumulated other comprehensive loss(12)(9)
Retained earnings11,090 8,422 
Total equity23,930 21,751 
Total liabilities and equity$93,845 $85,345 

The accompanying notes are an integral part of these consolidated financial statements.
57
Table of Contents
Consolidated Statements of Cash FlowsSouthern California Edison Company
Years ended December 31,
(in millions)202520242023
Cash flows from operating activities:
Net income$5,033 $1,794 $1,597 
Adjustments to reconcile to net cash provided by operating activities:
Depreciation and amortization3,233 2,865 2,633 
Equity allowance for funds used during construction(189)(187)(157)
Asset impairment106 — 1 
Deferred income taxes1,288 69 179 
Wildfire Fund amortization expense144 146 213 
Other125 120 110 
Nuclear decommissioning trusts(123)(174)(180)
Contributions to Wildfire Fund(95)(95)(95)
Changes in operating assets and liabilities:
Receivables661 (298)(336)
Inventory(4)(14)(63)
Accounts payable9 148 (413)
Other current assets and liabilities(231)(85)224 
Derivative assets and liabilities, net(11)28 (174)
Regulatory assets and liabilities, net(3,445)1,219 576 
Wildfire-related claims, net of insurance recoveries(607)(319)(449)
Other noncurrent assets and liabilities258 166 15 
Net cash provided by operating activities6,152 5,383 3,681 
Cash flows from financing activities:
Long-term debt issued, net of discount and issuance costs of $49, $36 and $37 for the respective years
4,593 4,214 3,588 
Long-term debt repaid(1,252)(2,201)(2,098)
Short-term debt borrowed410 — 706 
Short-term debt repaid(129)(386)(1,051)
Capital contributions from Edison International Parent— 500 — 
Preference stock issued, net of issuance cost— 345 542 
Preference stock redeemed and repurchased(504)(628)— 
Commercial paper (repayments) borrowing, net(504)94 963 
Common stock dividends paid(2,220)(1,440)(1,400)
Preference stock dividends paid(136)(168)(117)
Other11 (16)49 
Net cash provided by financing activities269 314 1,182 
Cash flows from investing activities:
Capital expenditures(6,512)(5,703)(5,446)
Proceeds from sale of nuclear decommissioning trust investments6,219 5,019 4,597 
Purchases of nuclear decommissioning trust investments(6,098)(4,898)(4,417)
Other62 52 35 
Net cash used in investing activities(6,329)(5,530)(5,231)
Net increase (decrease) in cash and cash equivalents and restricted cash and cash equivalents92 167 (368)
Cash and cash equivalents and restricted cash and cash equivalents at beginning of year565 398 766 
Cash and cash equivalents and restricted cash and cash equivalents at end of year$657 $565 $398 
The accompanying notes are an integral part of these consolidated financial statements.
58
Table of Contents
Consolidated Statements of Changes in EquitySouthern California Edison Company
Preference
Common
Additional
Paid-in
Capital		Accumulated
Other
Comprehensive
Loss		Retained
Earnings		Total
Equity
(in millions, except per share amounts)
Stock
Stock
Balance at December 31, 2022$1,945 $2,168 $8,441 $(8)$8,243 $20,789 
Net income— — — — 1,597 1,597 
Other comprehensive income— — — (4)— (4)
Dividends declared on common stock ($3.2422 per share)
— — — — (1,410)(1,410)
Dividends declared on preference stock ($96.8230 - $143.75 per share)
— — — — (123)(123)
Stock-based compensation— — (13)— — (13)
Noncash stock-based compensation— — 26 — — 26 
Preference stock issued
550 — (8)— — 542 
Balance at December 31, 2023$2,495 $2,168 $8,446 $(12)$8,307 $21,404 
Net income— — — — 1,794 1,794 
Other comprehensive income— — — 3 — 3 
Capital contribution from Edison International— — 500 — — 500 
Dividends declared on common stock ($3.4722 per share)
— — — — (1,510)(1,510)
Dividends declared on preference stock ($24.418 - $199.479 per share)
— — — — (154)(154)
Stock-based compensation— — (35)— — (35)
Noncash stock-based compensation— — 32 — — 32 
Preference stock issued350—(5)——345
Preference stock redeemed
(625)— 12 — (15)(628)
Balance at December 31, 2024$2,220 $2,168 $8,950 $(9)$8,422 $21,751 
Net income— — — — 5,033 5,033 
Other comprehensive income— — — (3)— (3)
Dividends declared on common stock ($5.1048 per share)
— — — — (2,220)(2,220)
Dividends declared on preference stock ($125.00 - $187.50 per share)
— — — — (136)(136)
Stock-based compensation— — (21)— — (21)
Noncash stock-based compensation— — 30 — — 30 
Preference stock redeemed and repurchased(506)— 11 — (9)(504)
Balance at December 31, 2025$1,714 $2,168 $8,970 $(12)$11,090 $23,930 

The accompanying notes are an integral part of these consolidated financial statements.
59
Table of Contents
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1. Summary of Significant Accounting Policies
Organization and Basis of Presentation
Edison International is the ultimate parent holding company of SCE and Edison Energy, LLC, doing business as Trio. SCE is an investor-owned public utility primarily engaged in the business of supplying and delivering electricity to an approximately 50,000 square mile area across Southern, Central, and Coastal California. Trio is a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial, and institutional customers. Trio's business activities are currently not material to report as a separate business segment, and SCE is the single reportable segment. See "Segment Information" below for further discussion.
These combined notes to the consolidated financial statements apply to both Edison International and SCE unless otherwise described. Edison International's consolidated financial statements include the accounts of Edison International, SCE, and other controlled subsidiaries. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to "Edison International Parent and Other" refer to Edison International Parent and its competitive subsidiaries and "Edison International Parent" refer to Edison International on a stand-alone basis, not consolidated with its subsidiaries. SCE's consolidated financial statements include the accounts of SCE, its controlled subsidiaries and a variable interest entity, SCE Recovery Funding LLC., of which SCE is the primary beneficiary. All intercompany transactions have been eliminated from the consolidated financial statements.
Edison International's and SCE's accounting policies conform to GAAP, including the accounting principles for rate-regulated enterprises, which reflect the ratemaking policies of the CPUC and the FERC. SCE applies authoritative guidance for rate-regulated enterprises to the portion of its operations in which regulators set rates at levels intended to recover the estimated costs of providing service, plus a return on net investments in assets, or rate base. Regulators may also impose certain penalties or grant certain incentives. Due to timing and other differences in the collection of electric utility revenue, these accounting principles require an incurred cost that would otherwise be charged to expense by a non-regulated entity to be capitalized as a regulatory asset if it is probable that the cost is recoverable through future rates; and conversely the accounting principles require recording of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. In addition, SCE recognizes revenue and regulatory assets from alternative revenue programs, which enables the utility to adjust future rates in response to past activities or completed events, if certain criteria are met. SCE assesses at the end of each reporting period whether regulatory assets are probable of future recovery. See Note 11 for the composition of regulatory assets and liabilities.
The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reported period. Actual results could differ from those estimates. Certain prior period amounts have been conformed to the current period's presentation.
Segment Information
The President and Chief Executive Officer ("CEO") of Edison International, as the chief operating decision maker ("CODM"), assesses Edison International’s performance and allocates resources based on its net income. This measure is reported as "Net income attributable to Edison International common shareholders" on Edison International's consolidated statements of income. The President and CEO of SCE, as its CODM, evaluates SCE's performance and allocates resources based on "Net income available for common stock" reported on SCE's consolidated statements of income. These net income measures are used by the Edison International and SCE CODMs to compare earnings from period to period and facilitate their respective assessment of performance of Edison International and SCE. The CODMs also use core earnings (loss) for financial planning and for additional analyses of performance. Core earnings (loss) is a non-GAAP financial measure which is defined as earnings available to shareholders less non-core items. Non-core items include income or loss from discontinued operations and income or loss from significant discrete items that management does not consider representative of ongoing earnings. Edison International's and SCE's significant segment expenses agree to those disclosed in the consolidated statements of income. The measures of Edison International's and SCE's segment assets are reported on Edison International's and SCE's consolidated balance sheets, respectively, as total assets.
60
Table of Contents
Cash and Cash Equivalents and Restricted Cash and Cash Equivalents
The following table sets forth the cash, cash equivalents, restricted cash and restricted cash equivalents included in the consolidated statements of cash flows:
Edison InternationalSCE
December 31,
(in millions)2025202420252024
Cash and cash equivalents1
$158 $193 $98 $78 
Short-term restricted cash and cash equivalents2
552 40 549 36 
Long-term restricted cash and cash equivalents3
10 451 10 451 
Total cash and cash equivalents and restricted cash and cash equivalents$720 $684 $657 $565 
1Cash equivalents consist of investments in money market funds. Generally, the carrying value of cash equivalents equals the fair value, as these investments have original maturities of three months or less.
2Includes SCE Recovery Funding LLC's restricted cash for payments of senior secured recovery bonds and cash collected for customer-funded wildfire self-insurance related to settlements (see Note 12 for further information). Both are reflected in "Other current assets" on Edison International's and SCE's consolidated balance sheets.
3Represents cash collected for customer-funded wildfire self-insurance and is reflected in "Other long-term assets" on Edison International's and SCE's consolidated balance sheets. See Note 12 for further information.
Allowance for Uncollectible Accounts
The allowance for uncollectible accounts is recorded based on SCE's estimate of expected credit losses and adjusted over the life of the receivables as needed. Since the customer base of SCE is concentrated in Southern California which exposes SCE to a homogeneous set of economic conditions, the allowance is measured on a collective basis on the historical amounts written-off, assessment of customer collectibility and current economic trends, including unemployment rates and any likelihood of recession for the region. The change in the provision of uncollectible accounts for the year ended December 31, 2025, was driven primarily by consumer protection programs that limit disconnections for nonpayment, and higher write-offs in 2025 was a result of lower collections in 2024.
The following table sets forth the changes in allowance for uncollectible accounts for SCE:
(in millions)CustomersAll othersTotal
Balance at December 31, 2022$334 $20 $354 
Current period provision for uncollectible accounts1
109 6 115 
Write-offs, net of recoveries(96)(9)(105)
Balance at December 31, 2023$347 $17 $364 
Current period provision for uncollectible accounts1
278 12 290 
Write-offs, net of recoveries(253)(11)(264)
Balance at December 31, 2024²$372 $18 $390 
Current period provision for uncollectible accounts1
356 41 397 
Write-offs, net of recoveries(368)(17)(385)
Balance at December 31, 2025²$360 $42 $402 
1This includes $296 million, $222 million, and $78 million of incremental costs for the years ended December 31, 2025, 2024, and 2023, respectively, which were probable of recovery from customers and recorded as regulatory assets.
2Approximately $49 million and $43 million of allowance for uncollectible accounts are included in "Other long-term assets" on SCE's consolidated balance sheets as of December 31, 2025 and 2024, respectively.
Inventory
SCE's inventory is primarily composed of materials, supplies and spare parts, and generally stated at weighted average cost or net realizable value when appropriate.
61
Table of Contents
Emission Allowances and Energy Credits
SCE is allocated GHG allowances annually which it is then required to sell into quarterly auctions. GHG proceeds from the auctions are recorded as a regulatory liability to be refunded to customers. SCE purchases GHG allowances in quarterly auctions or from counterparties to satisfy its GHG emission compliance obligations and recovers such costs of GHG allowances from customers. GHG allowances held for use are classified as "Other current assets" on the consolidated balance sheets and are stated, similar to an inventory method, at the lower of weighted average cost or market. SCE will evaluate GHG allowances for impairment upon a triggering event that would indicate SCE might not recover the full cost of an allowance. SCE had GHG allowances held for use of $110 million and $66 million at December 31, 2025 and 2024, respectively. GHG emission obligations were $19 million and $22 million at December 31, 2025 and 2024, respectively, and are classified as "Other current liabilities" on the consolidated balance sheets.
SCE is allocated low carbon fuel standard ("LCFS") credits which it sells to market participants. Proceeds from the sales, net of selling fees and program administration expenses, are recorded in a balancing account to be refunded to eligible customers. SCE's net proceeds from the sale of these LCFS credits were $219 million and $243 million at December 31, 2025 and 2024, respectively. LCFS credits are classified as "Regulatory liabilities" on the consolidated balance sheets.
Property, Plant and Equipment
SCE plant additions, including replacements and betterments, are capitalized. Direct material and labor and indirect costs such as construction overhead, administrative and general costs, employee benefits, and property taxes are capitalized as part of plant additions. The CPUC authorizes a capitalization rate for each of the indirect costs which are allocated to each project based on either labor or total costs.
Estimated useful lives authorized by the CPUC in the 2025 GRC and weighted average useful lives of SCE's property, plant and equipment, are as follows:
Estimated Useful LivesWeighted Average
Useful Lives
Generation plant
15 years to 57 years
38 years
Distribution plant
15 years to 66 years
49 years
Transmission plant
30 years to 70 years
54 years
General plant and other
5 years to 60 years
19 years
Depreciation of utility property, plant and equipment is computed on a composite straight-line, remaining-life basis. SCE's depreciation expense was $3.1 billion, $2.8 billion and $2.5 billion for 2025, 2024 and 2023, respectively. Depreciation expense stated as a percentage of average original cost of depreciable utility plant was, on a composite basis, 4.5%, 4.3% and 4.1% for 2025, 2024 and 2023, respectively. The original costs of retired property are charged to accumulated depreciation. See Note 2 for further information.
Nuclear fuel for Palo Verde is recorded as utility plant (nuclear fuel in the fabrication and installation phase is recorded as construction in progress) in accordance with CPUC ratemaking procedures. Palo Verde nuclear fuel is amortized using the units of production method.
Allowance for funds used during construction ("AFUDC") represents the estimated cost of debt and equity funds that finance utility-plant construction and is capitalized during certain plant construction. AFUDC is recovered in rates through depreciation expense over the useful life of the related asset. Equity AFUDC represents a method to compensate SCE for the estimated cost of equity used to finance utility plant additions and is recorded as part of construction in progress.
The following table summarizes SCE's AFUDC related to debt and equity:
Years ended December 31,
(in millions)202520242023
Debt AFUDC1
$86 $82 $74 
Equity AFUDC2
189 187 157 
1Reflected as a reduction of "Interest expense" on the consolidated statements of income.
2Reflected in "Other income" on the consolidated statements of income.
62
Table of Contents
Major Maintenance
Major maintenance costs for SCE's facilities and equipment are expensed as incurred.
Impairment of Long-Lived Assets
Impairments of long-lived assets are evaluated based on a review of estimated future cash flows expected to be generated whenever events or changes in circumstances indicate that the carrying amount of such investments or assets may not be recoverable. If the carrying amount of a long-lived asset exceeds expected future cash flows, undiscounted and without interest charges, an impairment loss is recognized in the amount of the excess of fair value over the carrying amount. Fair value is determined via market, cost and income-based valuation techniques, as appropriate.
Accounting principles for rate-regulated enterprises also require recognition of an impairment loss if it becomes probable that the regulated utility will abandon a plant investment, or if it becomes probable that the cost of a recently completed plant will be disallowed, either directly or indirectly, for ratemaking purposes, and a reasonable estimate of the disallowance amount can be made.
In September 2025, the CPUC issued a final decision in SCE's 2025 GRC proceeding. As a result of the decision, SCE recorded an $88 million impairment of utility property, plant and equipment that was disallowed by the CPUC, primarily related to the rooftop solar photovoltaic program.
In 2025, SCE recorded an impairment of $18 million related to utility property, plant and equipment associated with historical capital expenditures disallowed in the TKM and Woolsey Settlement Agreements.
Wildfire Fund
Senate Bill 254
SB 254 expands the Wildfire Fund originally created under AB 1054 by establishing the Continuation Account within the Wildfire Fund.
The Continuation Account became operative upon all three California investor-owned utilities, PG&E, SCE, and SDG&E (collectively, the "IOUs") electing to participate and agreeing to contribute to the Continuation Account if required.
The administrator of the Wildfire Fund will determine, on or before December 31, 2028, whether contributions to the Continuation Account are required, based on either of the following conditions: (a) the fund administrator projects that the original Wildfire Fund will be depleted within three years, or (b) a participating IOU notifies the fund administrator that it anticipates more than $1 billion in eligible claims in a single coverage year for one or more wildfires that ignite after the SB 254 Effective Date. If the fund administrator determines contributions are required, the CPUC will extend the non-bypassable charge imposed under AB 1054 until January 1, 2046 to collect customer contributions for the Continuation Account of $9 billion, and the IOUs will be required to contribute an initial aggregate amount of $5.1 billion (SCE's share is $2.4 billion) over the period 2029 through 2045. Additionally, if the fund administrator determines that additional contributions from IOUs are needed to enable the Continuation Account to fund the timely payment of eligible claims due to the likelihood of exhaustion of the fund, the fund administrator may require an additional aggregate contribution from the IOUs of $3.9 billion (the "Contingent Contribution" and SCE's share is $1.9 billion). If the administrator terminates the Continuation Account prior to the final installment of the Contingent Contribution, one-half of the remaining unpaid installment payments will be credited to customer rates.
As of December 31, 2025, and as of the date of this filing, the conditions required to trigger IOU contributions to the Continuation Account have not been met. Accordingly, SCE has not recorded a contribution obligation associated with the Continuation Account on its consolidated balance sheets as of December 31, 2025.
Wildfire Fund accounting and amortization life
Edison International and SCE accounted for the contributions to the Wildfire Fund similarly to prepaid insurance. No period of coverage was provided in the California Wildfire Legislation, therefore expense is being allocated to periods ratably based on an estimated period of coverage. At December 31, 2025 and 2024, Edison International and SCE had a $1.7 billion and a $1.9 billion long-term asset, respectively, as well as a $138 million current asset for both periods, reflected as "Wildfire Fund contributions" in their consolidated balance sheets for the initial $2.4 billion contribution made during 2019 and the present value of annual contributions SCE committed to make to the Wildfire Fund, reduced by amortization. At December 31, 2025 and 2024, long-term liabilities of $274 million and $363 million, respectively, have been reflected in "Other deferred credits and other long-term liabilities" for the present value of unpaid contributions. Contributions were discounted to the present value using US treasury interest rates at the date SCE committed to participate in the Wildfire Fund. Edison International and SCE reassesses the period of coverage of the fund at least annually in the first quarter each year, and adjustments are applied on a prospective basis. At December 31, 2025, 2024 and 2023, the asset
63
Table of Contents
was amortized based on an estimated period of coverage of 20 years, 20 years, and 15 years, respectively. All expenses related to the contributions are being reflected in "Wildfire Fund Expense" in the consolidated statements of income.
Changes in the estimated period of coverage provided by the Wildfire Fund could lead to material changes in future expense recognition. In 2025, management determined that the period of coverage for the Wildfire Fund, based on available historical data from wildfires caused by electrical utility equipment to estimate expected loss, continues to be an estimated 20 years from the date SCE committed to participate in the Wildfire Fund. SCE reassesses the period of coverage of the fund at least annually in the first quarter each year and when new or additional information becomes available. As of the date of this filing, after considering the current accrued losses for the Eaton Fire, SCE does not have new or additional information that would enable it to change its prior assessment that the Wildfire Fund would provide coverage for an estimated 20 years from the date SCE committed to participate in the Wildfire Fund. When updating its estimate, SCE includes all its fires for which losses can be reasonably estimated, and relies on publicly disclosed wildfire-related losses related to other participating utilities. As discussed in Note 12, while SCE believes that it will incur material losses in connection with the Eaton Fire, it is currently unable to reasonably estimate a range of losses that may be incurred. The Wildfire Fund amortization period will be evaluated and adjusted as new or additional information on contributions and wildfire events, including reasonably estimated losses related to the Eaton Fire, becomes available. As of December 31, 2025, the Wildfire Fund does not have any contribution associated with the Continuation Account.
As of December 31, 2025, SCE has recorded a receivable of $134 million from the Wildfire Fund, reflected in "Long-term insurance receivables." Based on California Wildfire legislation, a utility that submits claims to the Wildfire Fund for recovery is expected to receive such reimbursements from the Wildfire Fund, and separately file an application with CPUC for review of its costs and expenses. See Note 12 for further information. The outcome of the CPUC's prudency review could result in a refund to the Wildfire Fund. SCE will recognize a payable related to claim reimbursements to the Wildfire Fund if it determines that refund to the Wildfire Fund is probable and estimable. SCE will consider whether any party in the CPUC prudency review proceeding would prevail in raising a "serious doubt" as of the reasonableness of SCE's actions, and whether it is probable the CPUC would conclude that SCE does not meet the burden of dispelling that doubt and find SCE's conduct was not prudent. As of December 31, 2025, SCE determined it is not probable nor estimable that any amounts may be required to be reimbursed to the Wildfire Fund.
Contingencies
Edison International and SCE record loss contingencies when management determines that the outcome of future events is probable of occurring and when the amount of the loss can be reasonably estimated. For material contingencies when there is a reasonable possibility that a loss or an additional loss may be incurred, Edison International and SCE disclose the nature of the contingency and an estimate of the possible loss or range of loss or a statement that such an estimate cannot be made. Gain contingencies are recognized in the financial statements when they are realized. Legal costs expected to be incurred by Edison International and SCE in connection with loss contingencies are expensed as incurred.
The determination of an accrual for a loss contingency is based on management judgment and estimates with respect to the likely outcome of the matter, including the analysis of different scenarios. Recorded liabilities are adjusted when events or circumstances cause these judgments or estimates to change, including subsequent events. In assessing whether a loss is a reasonable possibility, Edison International and SCE may consider the following factors, among others: the nature of the litigation, claim or assessment, opinions or views of legal counsel and other advisors, and the experience gained from similar cases.
Nuclear Decommissioning and Asset Retirement Obligations
The fair value of a liability for an ARO is recorded in the period in which it is incurred, including a liability for the fair value of a conditional ARO, if the fair value can be reasonably estimated even though uncertainty exists about the timing and/or method of settlement. When an ARO liability is initially recorded, SCE capitalizes the cost by increasing the carrying amount of the related long-lived asset. For each subsequent period, the liability is increased for accretion expense and the capitalized cost is depreciated over the useful life of the related asset.
SCE has not recorded an ARO for assets that are expected to operate indefinitely or where SCE cannot estimate a settlement date (or range of potential settlement dates). As such, ARO liabilities are not recorded for certain retirement activities, including certain hydroelectric facilities.
64
Table of Contents
The following table summarizes the changes in SCE's ARO liability:
December 31,
(in millions)20252024
Beginning balance$2,580 $2,666 
Accretion1
145 137 
Revisions24 (2)
Liabilities settled(166)(221)
Ending balance$2,583 $2,580 
1Accretion is an increase in the liability to account for the time value of money for this present value liability.
AROs related to decommissioning of SCE's nuclear power facilities are based on site-specific studies conducted as part of each NDCTP conducted before the CPUC. ARO are revised when updated site-specific decommissioning cost estimates are available.
The ARO for decommissioning SCE's San Onofre and Palo Verde nuclear power facilities was $2.0 billion as of December 31, 2025. The liability to decommission SCE's nuclear power facilities is based on a 2024 decommissioning study, filed as part of the 2024 NDCTP, for Units 1, 2, and 3 and a 2023 decommissioning study for Palo Verde.
Due to regulatory recovery of SCE's nuclear decommissioning expense, prudently incurred costs for nuclear decommissioning activities do not affect SCE's earnings. Through the ratemaking process, SCE has substantially collected in rates, as a component of depreciation expense, all amounts for the future decommissioning of its nuclear assets and has placed those amounts in independent trusts. Amounts collected in rates in excess of the ARO liability are classified as ARO regulatory liabilities. See Note 11 for further information. Amortization of the ARO asset (included within the unamortized nuclear investment) and accretion of the ARO liability are deferred as decreases to the ARO regulatory liability account, resulting in no impact on earnings.
Changes in the estimated costs, timing of decommissioning or the assumptions underlying these estimates could cause material revisions to the estimated total cost to decommission. SCE currently estimates that it will spend approximately $7.4 billion through 2098 to decommission its nuclear facilities. This estimate is based on SCE's decommissioning cost methodology used for ratemaking purposes, escalated at rates ranging from 2.1% to 7.5% (depending on the cost element) annually. These costs are expected to be funded from independent decommissioning trusts. SCE estimates annual after-tax earnings on the decommissioning funds of 3.6% to 5.7% dependent on asset class. If the estimated costs increase, the assumed return on trust assets is not earned, or costs escalate at higher rates, SCE expects that additional funds needed for decommissioning will be recoverable through future rates, subject to a reasonableness review. See Note 10 for further information.
SCE's nuclear decommissioning costs are subject to CPUC review through the triennial regulatory proceedings. SCE's nuclear decommissioning trust investments primarily consist of fixed income investments that are classified as available-for-sale and equity investments. Due to regulatory mechanisms, investment earnings and realized gains and losses have no impact on earnings. Unrealized gains and losses on decommissioning trust funds, including impairment, increase or decrease the trust assets and the related regulatory asset or liability and have no impact on electric utility revenue or decommissioning expense. SCE reviews each fixed income security for impairment on the last day of each month. If the fair value on the last day of the month is less than the amortized cost for that security, SCE impairs the disclosed amortized cost. If the fair value is greater or less than the carrying value for that security at the time of sale, SCE recognizes a related realized gain or loss, respectively.
Deferred Financing Costs
Debt premium, discount, and issuance expenses incurred in connection with obtaining financing are deferred and amortized over the life of each debt issue. These deferred amounts are recorded as an offset to long-term debt. See Note 5 for further details. Under CPUC ratemaking procedures, SCE's debt reacquisition expenses are amortized over the remaining life of the reacquired debt, or if refinanced, the life of the new debt. The unamortized losses on reacquired debt are reflected as long-term "Regulatory assets" in the consolidated balance sheets. See Note 11 for further details.
Amortization of deferred financing costs charged to interest expense is as follows:
65
Table of Contents
Edison InternationalSCE
Years ended December 31,
(in millions)202520242023202520242023
Amortization of deferred financing costs charged to interest expense$36 $41 $39 $28 $34 $32 
Revenue Recognition
Revenue is recognized by Edison International and SCE when a performance obligation to transfer control of the promised goods is satisfied or when services are rendered to customers. This typically occurs when electricity is delivered to customers, which includes amounts for services rendered but unbilled at the end of a reporting period.
SCE's Revenue from Contracts with Customers
Provision of Electricity
SCE principally generates revenue through supplying and delivering electricity to its customers. Rates charged to customers are based on tariff rates, approved by the CPUC and FERC. Revenue is authorized through quadrennial GRC proceedings, which are intended to provide SCE a reasonable opportunity to recover its costs and earn a return on its CPUC-jurisdictional rate base. The CPUC sets an annual revenue requirement for the base year and the remaining three years are set by a methodology established in the GRC proceeding. As described above, SCE also earns revenue, with no return, to recover costs for power procurement, certain wildfire related expenses and other activities.
Revenue is authorized by the FERC through a formula rate which is intended to provide SCE a reasonable opportunity to recover transmission capital and operating costs that are prudently incurred, including a return on its FERC-jurisdictional rate base. Under the operation of the formula rate, transmission revenue is updated to actual cost of service annually.
For SCE's electricity sales for both residential and non-residential customers, SCE satisfies the performance obligation of delivering electricity over time as the customers simultaneously receive and consume the delivered electricity.
Energy sales are typically on a month-to-month implied contract for transmission, distribution and generation services. Revenue is recognized over time as the energy is supplied and delivered to customers and the respective revenue is billed and paid on a monthly basis.
CPUC and FERC rates decouple authorized revenue from the volume of electricity sales and the price of energy procured so that SCE has the opportunity to receive revenue equal to amounts authorized by the relevant regulatory agencies. As a result, the volume of electricity sold does not have a direct impact on SCE's financial results. See Note 7 for further information on SCE's revenue.
Sales and Use Taxes
SCE bills certain sales and use taxes levied by state or local governments to its customers. Included in these sales and use taxes are franchise fees, which SCE pays to various municipalities (based on contracts with these municipalities) in order to operate within the limits of the municipality. SCE bills these franchise fees to its customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SCE's ability to collect from the customer, are accounted for on a gross basis. SCE's franchise fees billed to customers were $182 million, $183 million, and $168 million for the years ended December 31, 2025, 2024, and 2023, respectively. When SCE acts as an agent for sales and use tax, the taxes are accounted for on a net basis. Amounts billed to and collected from customers for these taxes are remitted to the taxing authorities and are not recognized as electric utility revenue.
SCE's Alternative Revenue Programs
The CPUC and FERC have authorized additional, alternative revenue programs which adjust billings for the effects of broad external factors or provide for additional billings if the utility achieves certain objectives. These alternative revenue programs allow SCE to recover costs that SCE has been authorized to pass on to customers, including costs of certain capital and operations and maintenance activities, costs to purchase electricity and natural gas, and to fund public purpose, demand response, and customer energy efficiency programs, and earn a reasonable return. In general, revenue is recognized for these alternative revenue programs at the time the costs are incurred, or at the time when specific events permitting billing of the additional revenues have been completed. SCE begins recognizing revenues for these programs when a program has been established by an order from either the CPUC or FERC that allows for automatic adjustment of future rates, the amount of revenue for the period is objectively determinable and probable of recovery and the revenue will be collected within 24 months following the end of the annual period.
66
Table of Contents
Regulatory Proceedings
2025 General Rate Case
In September 2025, the CPUC approved a final decision in SCE's 2025 GRC, authorized a base rate revenue requirement of $9.7 billion for 2025, an increase of $1.1 billion over the revenue requirement authorized for 2024. See Note 11 for further information.
Power Purchase Agreements
SCE enters into power purchase agreements ("PPAs") in the normal course of business. A power purchase agreement may be considered a variable interest in a variable interest entity ("VIE"). If SCE is the primary beneficiary in the VIE, SCE is required to consolidate the VIE. None of SCE's PPAs resulted in consolidation at December 31, 2025 and 2024. See Note 3 for further discussion of PPAs that are considered variable interests.
A PPA may also contain a lease for accounting purposes. See "Leases" below and Note 12 and Note 13 for further discussion of SCE's PPAs. A PPA that does not contain a lease may be classified as a derivative which is recorded at fair value on the consolidated balance sheets, unless the PPA is eligible for an election to designate as a normal purchase or sale, which is accounted for on an accrual basis as an executory contract.
PPAs that do not meet the above classifications are accounted for on an accrual basis.
Derivative Instruments
SCE records derivative instruments on its consolidated balance sheets as either assets or liabilities measured at fair value unless otherwise exempted from derivative treatment as normal purchases or sales. The normal purchases and sales exception requires, among other things, physical delivery in quantities expected to be used or sold over a reasonable period in the normal course of business.
Realized gains and losses from SCE's derivative instruments are expected to be recovered from or refunded to customers through regulatory mechanisms and, therefore, SCE's fair value changes have no impact on purchased power expense or earnings. SCE does not use hedge accounting for derivative transactions due to regulatory accounting treatment.
Where SCE's derivative instruments are subject to a master netting agreement and certain criteria are met, SCE presents its derivative assets and liabilities on a net basis on its consolidated balance sheets. In addition, derivative positions are offset against margin and cash collateral deposits. The results of derivative activities are recorded as part of cash flows from operating activities on the consolidated statements of cash flows. See Note 6 for further information on derivative instruments.
Leases
A lease is defined as a contract, or part of a contract, that conveys the right to control the use of identified assets for a period of time in exchange for consideration. An entity controls the use when it has a right to obtain substantially all of the benefits from the use of the asset and has the right to direct the use. SCE determines if an arrangement is a lease at contract inception. For all classes of underlying assets, except battery storage assets where each component is separately accounted for, SCE accounts for lease and non-lease components as a single lease component. Lease liabilities are recognized based on the present value of the lease payments over the lease term at the commencement date. SCE calculates and uses the rate implicit in the lease if the information is readily available or if not available, SCE uses its incremental borrowing rate in determining the present value of lease payments. Incremental borrowing rates are comprised of underlying risk-free rates and secured credit spreads relative to first mortgage bonds with like tenors of lease term durations. Lease right-of-use ("ROU") assets are based on the liability, subject to adjustments, such as lease incentives. The ROU assets also include any lease payments made at or before the commencement date. SCE excludes variable lease payments in measuring lease assets and lease liabilities. SCE's lease terms include options to extend or terminate the lease when it is reasonably certain that such options will be exercised. SCE elected to exclude from the balance sheet short-term leases of one year or less.
SCE enters into power purchase agreements that may contain leases. This occurs when a power purchase agreement designates a specific power plant, SCE obtains substantially all of the economic benefits from the use of the plant and has the right to direct the use of the plant. SCE also enters into a number of agreements to lease property and equipment in the normal course of business, primarily related to vehicles, office space and other equipment. See Note 13 for further information on leases.
Edison International Parent and Other's leases primarily relate to Trio, which are immaterial to Edison International.
67
Table of Contents
Stock-Based Compensation
Stock options, performance shares, deferred stock units, and restricted stock units have been granted under Edison International's long-term incentive compensation programs. For equity awards that are settled in common stock, Edison International either issues new common stock, or uses a third party to purchase shares from the market and deliver such shares for the settlement of the awards. Stock options, performance shares, deferred stock units and restricted stock units are settled in common stock. For awards that are otherwise settled entirely in common stock, Edison International withholds or sells shares or substitutes cash awards to the extent necessary to satisfy applicable tax withholding obligations or government levies.
Stock-based compensation expense is recognized, net of estimated forfeitures, on a straight-line basis over the requisite service period based on estimated fair values. For equity awards paid in common stock, fair value is determined at the grant date. For equity awards that have market conditions defined in the grants, expense is recognized based on grant date fair value if the requisite service period is fulfilled. However, with respect to the portion of the performance shares payable in common stock that are subject to financial performance conditions defined in the grants, the number of performance shares expected to be earned is subject to revision and updated at each reporting period, with a related adjustment to compensation expense.
For awards granted to retirement-eligible participants, stock compensation expense is recognized on a prorated basis over the initial year. For awards granted to participants who become eligible for retirement during the requisite service period, stock compensation expense is recognized over the period between the date of grant and the date the participant first becomes eligible for retirement. Edison International and SCE estimate the number of awards that are expected to vest rather than account for forfeitures when they occur. Share-based payments may create a permanent difference between the amount of compensation expense recognized for book and tax purposes. The tax impact of this permanent difference is recognized in earnings in the period it is created. See Note 9 for further information.
Employee Stock Purchase Plan
The Edison International Employee Stock Purchase Plan ("ESPP"), effective beginning July 2021, allows eligible employees to make purchases of Edison International's common stock. The maximum aggregate numbers of shares that may be issued under the ESPP is 3,000,000 shares. Eligible employees may authorize payroll deductions of between 1% and 10% of their eligible base compensation, to purchase shares of common stock at 97% of the market price on the last day of each six months offering period. An eligible employee may purchase up to $25,000 worth of Edison International's common stock per calendar year under the ESPP. The ESPP is considered noncompensatory and stock issuances under the ESPP are recorded directly in equity.
SCE Dividends
CPUC holding company rules require that SCE's dividend policy be established by the SCE Board of Directors on the same basis as if SCE were a stand-alone utility company, and that the capital requirements of SCE, as deemed to be necessary to meet SCE's electricity service obligations, shall receive first priority from the Boards of Directors of both Edison International and SCE. In addition, the CPUC regulates SCE's capital structure which limits the dividends it may pay to its shareholders.
The common equity component of SCE's CPUC authorized capital structure is 52% on a weighted average basis over the Capital Structure Compliance Period, unchanged from the January 1, 2023 to December 31, 2025 compliance period. The CPUC authorized capital structure differs from the capital structure calculated based on GAAP due to certain exclusions allowed by CPUC, including the impact of SCE's contributions to the Wildfire Fund under the California Wildfire Legislation.
In January and December 2025, the CPUC approved the TKM Settlement Agreement and the Woolsey Settlement Agreement, under which SCE is allowed to permanently exclude any after-tax charges to equity associated with the costs disallowed or funded by shareholders in the TKM Settlement Agreement and Woolsey Settlement Agreement, and the debt issued to finance those costs.
SCE monitors its compliance with the CPUC's equity ratio requirement based on the weighted average of the common equity component of SCE's CPUC authorized capital structure over the Capital Structure Compliance Period using its actual capital structure from the beginning of the Capital Structure Compliance Period through the reporting date together with forecasted performance and expected financing activities for the remainder of the Capital Structure Compliance Period. SCE expects to be compliant with its CPUC authorized capital structure at the end of the Capital Structure Compliance Period.
SCE's ability to declare and pay common dividends may be restricted under the terms of its outstanding series of preference stock. For further information see Note 14.
68
Table of Contents
As a California corporation, SCE's ability to pay dividends is also governed by the California General Corporation Law. California law requires that for a dividend to be declared: (a) retained earnings must equal or exceed the proposed dividend, or (b) immediately after the dividend is made, the value of the corporation's assets must exceed the value of its liabilities plus amounts required to be paid, if any, in order to liquidate stock senior to the shares receiving the dividend. Additionally, a California corporation may not declare a dividend if it is, or as a result of the dividend would be, likely to be unable to meet its liabilities as they mature. Prior to declaring dividends, the SCE Board of Directors evaluates available information, including when applicable, information pertaining to wildfire events, to ensure that the California law requirements for the declarations are met. On February 18, 2026, SCE declared a dividend to Edison International of $430 million.
The timing and amount of future dividends are also dependent on a number of other factors including SCE's requirements to fund other obligations and capital expenditures, and its ability to access the capital markets and generate operating cash flows and earnings. If SCE incurs significant costs related to catastrophic wildfires and is unable to recover such costs through insurance, the Wildfire Fund (for fires after July 12, 2019), or from customers or is unable to access capital markets on reasonable terms, SCE may be limited in its ability to pay future dividends to Edison International and its preference shareholders.
Edison International Dividend
Edison International's ability to declare and pay common dividends may be restricted under the terms of its outstanding preferred stock. For further information see Note 14.
In December 2025, Edison International declared a 6.0% increase to the annual dividend rate from $3.31 per share to $3.51 per share. On February 18, 2026, Edison International declared a dividend of $0.8775 per share to be paid on April 30, 2026. Edison International intends to maintain its target payout ratio of 45% – 55% of SCE's core earnings.
Earnings Per Share
Edison International computes earnings per common share ("EPS") using the two-class method, which is an earnings allocation formula that determines EPS for each class of common stock and participating security. Edison International's participating securities are stock-based compensation awards, payable in common shares, which earn dividend equivalents on an equal basis with common shares once the awards are vested. See Note 9 and Note 14 for further information.
EPS available to Edison International common shareholders was computed as follows:
Years ended December 31,
(in millions, except per-share amounts)202520242023
Basic earnings per share:
Net income available to Edison International common shareholders$4,459 $1,284 $1,197 
Earnings allocated to participating securities
(2)— — 
Income available to common shareholders
$4,457 $1,284 $1,197 
Weighted average common shares outstanding385 386 383 
Basic earnings per share$11.58 $3.33 $3.12 
Diluted earnings per share:
Income available to common shareholders$4,457 $1,284 $1,197 
Add back: Earnings allocated to participating securities2 1 1 
Net income available to Edison International common shareholders$4,459 $1,285 $1,198 
Weighted average common shares outstanding385 386 383 
Effect of dilutive securities1 2 2 
Adjusted weighted average shares – diluted386 388 385 
Diluted earnings per share$11.55 $3.31 $3.11 
In addition to the participating securities discussed above, Edison International also may award stock options, which are payable in common shares and are included in the diluted earnings per share calculation. Stock option awards to purchase 8,891,163, 1,533,982, and 3,771,766 of common stock for the years ended December 31, 2025, 2024, and 2023, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the effect would have been antidilutive.
69
Table of Contents
Income Taxes
Edison International and SCE estimate their income taxes for each jurisdiction in which they operate. This involves estimating current period tax expense along with assessing temporary differences resulting from the differing treatment of items (such as depreciation) for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are included in the consolidated balance sheets.
Income tax expense includes the current tax liability from operations and the change in deferred income taxes during the year. Interest income, interest expense, and penalties associated with income taxes are generally reflected in "Income tax expense (benefit)" on the consolidated statements of income.
Investment tax credits are generally deferred and amortized to income tax expense over the lives of the related properties. The scope of projects eligible for investment tax credits was expanded in 2023 to include standalone energy storage projects. The Inflation Reduction Act provided an election that permits investment tax credits related to standalone energy storage projects to be returned to utility customers over a period that is shorter than the life of the related property.
Edison International's eligible subsidiaries are included in Edison International's consolidated federal income tax and combined state tax returns. Edison International has tax-allocation and payment agreements with certain of its subsidiaries. Pursuant to an income tax-allocation agreement approved by the CPUC, SCE's tax liability is computed as if it filed its federal and state income tax returns on a separate return basis.
New Accounting Guidance
Accounting Guidance Adopted
In December 2023, the FASB issued an accounting standards update requiring additional disclosures primarily related to the income tax rate reconciliation and income taxes paid. The guidance also eliminates certain existing disclosures related to uncertain tax positions and unrecognized deferred tax liabilities. Edison International and SCE have applied this standard in the annual disclosure for the year ended December 31, 2025. See Note 8 for further information.
Accounting Guidance Not Yet Adopted
In November 2024, the FASB issued an accounting standards update requiring public entities to provide disaggregated disclosure of income statement expenses. The guidance does not change the expense captions an entity presents on the face of the income statement, rather, it requires disaggregation of certain expense captions into specified categories in disclosures within the footnotes to the financial statements. The guidance is effective for annual disclosure for the year ended December 31, 2027 and subsequent interim periods with early adoption permitted. The guidance is applied prospectively. Edison International and SCE are currently evaluating the impact of this new guidance.
In September 2025, the FASB issued an accounting standards update to amend certain aspects of the accounting for and disclosure of internal-use software. Among other things, the guidance removes all references to prescriptive and sequential software development stages and instead requires entities to begin capitalizing software costs when certain criteria are met. The guidance is effective for annual periods after January 1, 2028 and interim reporting periods within those annual reporting periods with early adoption permitted. The guidance can be applied prospectively, retrospectively, or via a modified prospective transition method. Edison International and SCE are currently evaluating the impact of this new guidance.
In December 2025, the FASB issued an accounting standards update to establish guidance on the recognition, measurement, and presentation of government grants received by business entities. The guidance is effective in annual periods beginning after January 1, 2029 and interim periods within those annual reporting periods with early adoption permitted. The guidance can be applied on a modified prospective basis, a modified retrospective basis, or a full retrospective basis. Edison International and SCE are currently evaluating the impact of this new guidance.
70
Table of Contents
Note 2. Property, Plant and Equipment
SCE's utility property, plant and equipment included in the consolidated balance sheets is composed of the following:
December 31,
(in millions)20252024
Distribution$39,776 $37,093 
Transmission19,959 19,189 
Generation4,297 4,217 
General plant and other7,309 7,046 
Accumulated depreciation(15,060)(14,207)
56,281 53,338 
Construction work in progress1
6,720 5,585 
Nuclear fuel, at amortized cost130 124 
Total utility property, plant and equipment$63,131 $59,047 
1Includes $996 million and $611 million of capitalized software costs at December 31, 2025 and 2024, respectively.
Capitalized Software Costs
SCE capitalizes costs incurred during the application development stage of internal use software projects to property, plant and equipment. SCE amortizes capitalized software costs ratably over their useful lives, primarily 5 and 7 year lives, commencing upon operational use. Capitalized software costs, included in general plant and other above, was $2.7 billion and $2.5 billion at December 31, 2025 and 2024, respectively, and accumulated amortization was $1.3 billion and $1.1 billion, at December 31, 2025 and 2024, respectively. Amortization expense for capitalized software was $463 million, $416 million, and $358 million in 2025, 2024, and 2023, respectively.
Jointly Owned Utility Projects
SCE owns undivided interests in transmission and generating assets for which each participant provides its own financing. SCE's proportionate share of these assets is reflected in the consolidated balance sheets and included in the above table. SCE's proportionate share of expenses for each project is reflected in the consolidated statements of income.
The following is SCE's investment in each asset as of December 31, 2025:
(in millions)Plant in
Service		Construction
Work in
Progress		Accumulated
Depreciation		Nuclear Fuel
(at amortized cost)		TotalOwnership
Interest
Transmission systems:
Eldorado$511 $1 $(74)$— $438 72 %
Pacific Intertie356 9 (128)— 237 50 %
Generating station:
Palo Verde (nuclear)2,265 99 (1,713)130 781 16 %
Total$3,132 $109 $(1,915)$130 $1,456 
In addition to the jointly owned assets in the table above, SCE has ownership interests in jointly owned power poles with other companies.
Note 3. Variable Interest Entities
A VIE is defined as a legal entity that meets any of the following conditions: (1) the total equity investment at risk is not sufficient to fund the entity's activities without additional subordinated financial support, (2) the equity holders as a group, lack any of the following characteristics: the power to direct activities that most significantly impact the entity's economic performance, substantive voting rights, the obligation to absorb losses, or the right to receive the expected residual returns of the entity. The primary beneficiary is identified as the variable interest holder that has both the power to direct the activities of the VIE that most significantly impact the entity's economic performance, and the obligation to absorb losses or the right to receive benefits from the entity that could potentially be significant to the VIE. The primary beneficiary is required to consolidate the VIE. Commercial and operating activities are generally the factors that most significantly impact the economic performance of such VIEs.
71
Table of Contents
Variable Interest in VIEs that are Consolidated
SCE Recovery Funding LLC is a bankruptcy remote, wholly owned special purpose subsidiary of SCE, formed for the purpose of issuing securitized bonds. This entity is a VIE because its equity investment is insufficient to support its operations. The most significant activity of SCE Recovery Funding LLC is to service the securitized bonds according to the decisions made by SCE. Therefore, SCE is determined to be the primary beneficiary and consolidates SCE Recovery Funding LLC.
SCE Recovery Funding LLC has issued a total of $3.2 billion of securitized bonds at December 31, 2025. The proceeds were used to acquire SCE's right, title and interest in and to non-bypassable rates and other charges to be collected from certain existing and future customers in SCE's service area ("Recovery Property"), associated with the AB 1054 Excluded Capital Expenditures and costs approved for recovery under the TKM Settlement Agreement, until the bonds are paid in full, and all financing costs have been recovered. The securitized bonds are secured by the Recovery Property and cash collections from the non-bypassable rates and other charges are the sole source of funds to satisfy the debt obligation. The bondholders have no recourse to SCE. For further details, see Note 5.
The following table summarizes the impact of SCE Recovery Funding LLC on SCE's and Edison International's consolidated balance sheets.
December 31,
(in millions)20252024
Other current assets$49 $49 
Regulatory assets: non-current3,092 1,512 
Regulatory liabilities: current12 30 
Current portion of long-term debt1
78 49 
Other current liabilities14 6 
Long-term debt1
3,022 1,468 
1The bondholders have no recourse to SCE. The long-term debt balance is net of unamortized debt issuance costs.
Variable Interest in VIEs that are not Consolidated
Power Purchase Agreements
SCE has certain PPAs where the counterparty entities meet one or both of the VIE conditions discussed above and in which SCE has variable interests, including: agreements through which SCE provides natural gas to fuel the plants, fixed price contracts for renewable energy, and resource adequacy agreements that allow purchase of energy at fixed prices upon the seller's election. Since payments for capacity are the primary source of income, the most significant economic activity for these VIEs is typically the operation and maintenance of the power plants, which SCE does not perform. Therefore, SCE has concluded that it is not the primary beneficiary of any of these VIEs because it does not control the commercial and operating activities that most significantly impact the economic performance of these entities.
As of the balance sheet date, the carrying amount of assets and liabilities included in SCE's consolidated balance sheet that relate to involvement with VIEs that are not consolidated, result from amounts due under the PPAs. Under these contracts, SCE recovers the costs incurred through demonstration of compliance with its CPUC-approved long-term power procurement plans. SCE has no residual interest in the entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees, or other commitments associated with these contracts other than the purchase commitments described in Note 12. As a result, there is no significant potential exposure to loss to SCE from its variable interest in these VIEs. The aggregate contracted capacity dedicated to SCE from these VIE projects was 6,024 MW and 5,200 MW at December 31, 2025 and 2024, respectively, and the amounts that SCE paid to these projects were $899 million and $778 million for the years ended December 31, 2025 and 2024, respectively. These amounts are recoverable in customer rates, subject to a reasonableness review.
Note 4. Fair Value Measurements
Recurring Fair Value Measurements
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (referred to as an "exit price"). Fair value of an asset or liability considers assumptions that market participants would use in pricing the asset or liability, including assumptions about nonperformance risk. As of December 31, 2025 and 2024, nonperformance risk was not material for Edison International or SCE.
72
Table of Contents
Assets and liabilities are categorized into a three-level fair value hierarchy based on valuation inputs used to determine fair value.
Level 1 – The fair value of Edison International's and SCE's Level 1 assets and liabilities is determined using unadjusted quoted prices in active markets that are available at the measurement date for identical assets and liabilities. This level includes exchange-traded equity securities, U.S. treasury securities, mutual funds, and money market funds.
Level 2 – Edison International's and SCE's Level 2 assets and liabilities include fixed income securities, primarily consisting of U.S. government and agency bonds, municipal bonds and corporate bonds, and over-the-counter commodity derivatives. The fair value of fixed income securities is determined using a market approach by obtaining quoted prices for similar assets and liabilities in active markets and inputs that are observable, either directly or indirectly, for substantially the full term of the instrument.
The fair value of SCE's over-the-counter commodity derivative contracts is determined using an income approach. SCE uses standard pricing models to determine the net present value of estimated future cash flows. Inputs to the pricing models include forward published or posted clearing prices from an exchange (Intercontinental Exchange) for similar instruments and discount rates. A primary price source that best represents trade activity for each market is used to develop observable forward market prices in determining the fair value of these positions. Broker quotes, prices from exchanges or comparison to executed trades are used to validate and corroborate the primary price source. These price quotations reflect mid-market prices (average of bid and ask) and are obtained from sources believed to provide the most liquid market for the commodity.
Level 3 – This level primarily consists of congestion revenue rights ("CRRs"), which are derivative contracts that trade infrequently with significant unobservable inputs (CAISO CRR auction prices). SCE employs a market valuation approach of utilizing historical CRR prices as a proxy for forward prices. SCE also enters into certain physically settled resource adequacy contracts with a financially settled electricity component ("Fin Toll arrangements"). For these Fin Toll arrangements, SCE uses an income model valuation approach to estimate the significant unobservable inputs (hourly power prices). Edison International Parent and Other does not have any Level 3 assets and liabilities.
Assumptions are made in order to value derivative contracts in which observable inputs are not available. In circumstances where fair value cannot be verified with observable market transactions, it is possible that a different valuation model could produce a materially different estimate of fair value. Modeling methodologies, inputs, and techniques are reviewed and assessed as markets continue to develop and more pricing information becomes available and the fair value is adjusted when it is concluded that a change in inputs or techniques would result in a new valuation that better reflects the fair value of those derivative contracts. See Note 6 for a discussion of derivative instruments.
SCE
The following table sets forth assets and liabilities of SCE that were accounted for at fair value by level within the fair value hierarchy:
December 31, 2025
(in millions)Level 1Level 2Level 3
Netting
and
Collateral1
Total
Assets at fair value
Derivative contracts$— $— $48 $— $48 
Money market funds and other34 22 — — 56 
Nuclear decommissioning trusts:
Stocks2
1,909 — — — 1,909 
Fixed Income3
981 1,665 — — 2,646 
Short-term investments, primarily cash equivalents191 40 — — 231 
Subtotal of nuclear decommissioning trusts4
3,081 1,705 — — 4,786 
Total assets3,115 1,727 48 — 4,890 
Liabilities at fair value
Derivative contracts— 57 — (57)— 
Total liabilities— 57 — (57)— 
Net assets$3,115 $1,670 $48 $57 $4,890 
73
Table of Contents
December 31, 2024
(in millions)Level 1Level 2Level 3
Netting
and
Collateral1
Total
Assets at fair value
Derivative contracts$— $1 $212 $(1)$212 
Other— 22 — — 22 
Nuclear decommissioning trusts:
Stocks2
1,631 — — — 1,631 
Fixed Income3
975 1,618 — — 2,593 
Short-term investments, primarily cash equivalents128 39 — — 167 
Subtotal of nuclear decommissioning trusts4
2,734 1,657 — — 4,391 
Total assets2,734 1,680 212 (1)4,625 
Liabilities at fair value
Derivative contracts— 47 — (47)— 
Total liabilities— 47 — (47)— 
Net assets$2,734 $1,633 $212 $46 $4,625 
1Represents the netting of assets and liabilities under master netting agreements and cash collateral.
2Approximately 71% and 75% of SCE's equity investments were in companies located in the United States at December 31, 2025 and 2024, respectively.
3Includes corporate bonds, which were diversified by the inclusion of collateralized mortgage obligations and other asset backed securities of $60 million and $94 million at December 31, 2025 and 2024, respectively.
4Excludes net payables of $251 million and $105 million at December 31, 2025 and 2024, respectively, which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases.
SCE Fair Value of Level 3
The following table sets forth a summary of changes in SCE's fair value of Level 3 net derivative assets and liabilities:
Years ended December 31,
(in millions)20252024
Fair value of net assets at beginning of period$212 $91 
Sales— (1)
Settlements(42)14 
Total realized/unrealized (losses) gains1
(122)108 
Fair value of net assets at end of period$48 $212 
1Due to regulatory mechanisms, SCE's realized and unrealized gains and losses are recorded as regulatory assets and liabilities.
There were no material transfers into or out of Level 3 during 2025 and 2024.
74
Table of Contents
The following table sets forth the significant unobservable inputs used to determine fair value for Level 3 assets and liabilities:
Fair Value
(in millions)		Significant
Unobservable
Input		Range
($ per MWh)		Weighted
Average
($ per MWh)
AssetsLiabilities
December 31, 2025
CRRs$43 $— CAISO CRR auction prices
$(5.28) - $14,484.70
$8.39 
Fin Toll arrangements5 — Hourly forecast power prices
$0.00 - $97.04
42.16 
December 31, 2024
CRRs$212 $— CAISO CRR auction prices
$(4.64) - $50,048.16
$27.20 
Level 3 Fair Value Uncertainty
For CRRs, increases or decreases in CAISO auction prices would result in higher or lower fair value, respectively.
For Fin Toll arrangements, the fair value measurements are sensitive to the spread between daily high and daily low hourly power prices. Increases or decreases in this spread would result in higher or lower fair value, respectively.
Nuclear Decommissioning Trusts
SCE's nuclear decommissioning trust investments include equity securities, U.S. treasury securities and other fixed income securities. Equity and treasury securities are classified as Level 1 as fair value is determined by observable market prices in active or highly liquid and transparent markets. The remaining fixed income securities are classified as Level 2. The fair value of these financial instruments is based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes, issuer spreads, bids, offers and relevant credit information. There are no securities classified as Level 3 in the nuclear decommissioning trusts.
SCE's investment policies and CPUC requirements place limitations on the types and investment grade ratings of the securities that may be held by the nuclear decommissioning trust funds. These policies restrict the trust from holding alternative investments and limit the trust funds' exposures to investments in highly illiquid markets. With respect to equity and fixed income securities, the trustee obtains prices from third-party pricing services which SCE is able to independently corroborate as described below. The trustee monitors prices supplied by pricing services, including reviewing prices against defined parameters' tolerances and performs research and resolves variances beyond the set parameters. SCE corroborates the fair values of securities by comparison to other market-based price sources obtained by SCE's investment managers. Differences outside established thresholds are followed-up with the trustee and resolved. For each reporting period, SCE reviews the trustee determined fair value hierarchy and overrides the trustee level classification when appropriate. See Note 10 for more information on nuclear decommissioning trusts.
Edison International Parent and Other
Edison International Parent and Other assets measured at fair value and classified as Level 1 consisted of money market funds of $51 million and $101 million at December 31, 2025 and 2024, respectively. Assets measured at fair value and classified as Level 2 were immaterial at December 31, 2025 and 2024. There were no securities classified as Level 3 for Edison International Parent and Other at December 31, 2025 and 2024.
Fair Value of Debt Recorded at Carrying Value
The carrying value and fair value of Edison International's and SCE's long-term debt (including current portion of long-term debt) are as follows:
December 31, 2025December 31, 2024
(in millions)
Carrying
Value1
Fair
Value2
Carrying
Value1
Fair
Value2
Edison International$37,998 $35,721 $35,583 $33,160 
SCE33,183 30,744 30,515 27,994 
1Carrying value is net of debt issuance costs.
2The fair value of long-term debt is classified as Level 2.
75
Table of Contents
Note 5. Debt and Credit Agreements
Long-Term Debt
The following table summarizes long-term debt (rates and terms are as of December 31, 2025) of Edison International and SCE:
December 31,
(in millions)20252024
Edison International Parent:
Debentures and notes:
2027 – 2054 (4.125% to 8.125%)
$4,850 $5,100 
Current portion of long-term debt— (800)
Unamortized debt discount/premium and issuance costs, net(35)(32)
Total Edison International Parent4,815 4,268 
SCE:
First and refunding mortgage bonds:
2026 – 2055 (1.20% to 6.20%)
29,200 27,400 
Pollution-control bonds:
2028 – 2035 (1.45% to 4.50%)
752 752 
Debentures and notes:
2029 – 2053 (5.06% to 6.65%)
306 306 
Senior secured recovery bonds1:
2028 – 2050 (0.86% to 5.54%)
3,126 1,532 
Other long-term debt2
— 706 
Current portion of long-term debt(1,928)(1,249)
Unamortized debt discount/premium and issuance costs, net(201)(181)
Total SCE31,255 29,266 
Total Edison International$36,070 $33,534 
1The senior secured recovery bonds are payable only from and secured by the Recovery Property at SCE Recovery Funding LLC, and do not constitute a debt or other legal obligation of, or interest in, SCE or any of its affiliates, except for SCE Recovery Funding LLC. For further details, see Note 3.
2Subsequent to December 31, 2024, SCE issued first and refunding mortgage bonds which were used to partially pay down its commercial paper balance. As a result, SCE included the paydown amount of $706 million in other long-term debt at December 31, 2024.
Edison International and SCE long-term debt maturities over the next five years are as follows:
(in millions)Edison InternationalSCE
2026$1,928 $1,928 
20272,538 1,938 
20282,981 1,831 
20293,404 2,354 
20302,048 1,498 
Senior Secured Recovery Bonds
In December 2025, SCE Recovery Funding LLC issued $1.6 billion of Senior Secured Recovery Bonds, Series 2025-A, in three tranches ("Recovery Bonds") consisting of: $443 million, 4.45% with final maturity in 2038; $600 million, 5.34% with final maturity in 2047; and $600 million, 5.54% with final maturity in 2052. SCE used the proceeds it received from
76
Table of Contents
the sale of Recovery Property to reimburse itself for costs approved for recovery under the TKM Settlement Agreement. For further details, see Note 3.
Liens and Security Interests
Almost all of SCE's properties are subject to a trust indenture lien. SCE has pledged first and refunding mortgage bonds as collateral for borrowed funds obtained from pollution-control bonds issued by government agencies. SCE has a debt covenant that requires a debt to total capitalization ratio to be less than or equal to 0.65 to 1. At December 31, 2025, SCE's debt to total capitalization ratio was 0.57 to 1 and was in compliance with all other financial covenants that affect access to capital. Edison International Parent's credit facility requires a consolidated debt to total capitalization ratio as defined in the applicable agreements of less than or equal to 0.70 to 1. At December 31, 2025, Edison International consolidated debt to total capitalization ratio was 0.64 to 1.
Credit Agreements and Short-Term Debt
The following table summarizes the status of the credit facilities at December 31, 2025:
(in millions, except for rates)
BorrowerTermination DateSOFR plus (bps)CommitmentOutstanding borrowingsOutstanding letters of creditAmount available
Edison International Parent1, 3
May 2029128$1,500 $756 $— $744 
SCE2, 3
May 20291083,350 1,038 2 2,310 
Total Edison International$4,850 $1,794 $2 $3,054 
1At December 31, 2025 and 2024, Edison International Parent had $754 million and $444 million outstanding commercial paper, net of discount of $2 million and $1 million, at a weighted-average interest rate of 4.58% and 4.86%, respectively.
2At December 31, 2025 and 2024, SCE had $1,036 million and $1,259 million outstanding commercial paper, net of discount of $2 million and $1 million, at a weighted-average interest rate of 4.59% and 4.95%, respectively. The balance at December 31, 2024 includes $706 million outstanding commercial paper reclassified from "Short-term debt" to "Long-term debt" on the consolidated balance sheet due to subsequent debt refinancing.
3The aggregate maximum principal amount under the Edison International Parent and SCE revolving credit facilities may be increased up to $2.0 billion and $4.0 billion, respectively, provided that additional lender commitments are obtained.
Term Loan
In December 2025, Edison International Parent borrowed $600 million under a term loan agreement due in December 2026 with a variable interest rate based on either SOFR plus 1.25% or a base rate plus 0.25%. The proceeds were used for general corporate purposes.
Uncommitted Letters of Credit
SCE has agreements with certain lenders for bilateral unsecured standby letters of credit ("SBLC") with a total capacity of $660 million that is uncommitted and supported by reimbursement agreements. The SBLCs are not subject to any collateral or security requirements. At December 31, 2025, SCE had $147 million in standby letters of credit outstanding under these agreements, which expire between January 2026 and January 2027.
Debt Financing Subsequent to December 31, 2025
In February 2026, SCE entered into a term loan agreement to borrow up to $300 million that mature in March 2027 with a variable interest rate based on either SOFR plus 1.00% or a base rate. The proceeds were used for general corporate and working capital purposes.
Note 6. Derivative Instruments
Derivative financial instruments are used to manage exposure to commodity price risk resulting from SCE's electricity and natural gas procurement activities. The risks of fluctuating commodity prices are managed in part by entering into forward commodity transactions, including options, swaps, and futures. To mitigate credit risk from counterparties in the event of nonperformance, master netting agreements are used whenever possible, and counterparties may be required to pledge collateral depending on the creditworthiness of each counterparty and the risk associated with the transaction.
Certain power and gas contracts contain a provision that requires SCE to maintain an investment grade rating from the major credit rating agencies, referred to as a credit-risk-related contingent feature. If SCE's credit rating were to fall below
77
Table of Contents
investment grade, SCE may be required to post additional collateral to cover derivative liabilities and the related outstanding payables. The fair value of these derivative contracts were immaterial as of December 31, 2025 and 2024, for which SCE posted collateral of $54 million and no collateral to its counterparties for its outstanding payables as of December 31, 2025, and 2024, respectively. If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2025, SCE would be required to post an additional $3 million of collateral, most of which is related to outstanding payables.
SCE presents its derivative assets and liabilities, recorded at fair value, on a net basis on its consolidated balance sheets when subject to master netting agreements or similar agreements. Derivative positions are also offset against margin and cash collateral deposits. See Note 4 for a discussion of fair value of derivative instruments.
The following table summarizes the gross and net fair values of SCE's commodity derivative instruments:
December 31, 2025
(in millions)
Derivative Assets
Short-Term1
Derivative Liabilities
Short-Term2
Commodity derivative contracts
Gross amounts recognized$48 $57 
Gross amounts offset in the consolidated balance sheets— — 
Cash collateral posted— (57)
Net amounts presented in the consolidated balance sheets$48 $— 
December 31, 2024
(in millions)
Derivative Assets
Short-Term1
Derivative Liabilities
Short-Term2
Commodity derivative contracts
Gross amounts recognized$213 $47 
Gross amounts offset in the consolidated balance sheets(1)(1)
Cash collateral posted— (46)
Net amounts presented in the consolidated balance sheets$212 $— 
1Included in "Other current assets" on SCE's consolidated balance sheets.
2Included in "Other current liabilities" on SCE's consolidated balance sheets.
At December 31, 2025, SCE posted $66 million of cash collateral, of which $57 million was offset against derivative liabilities and $9 million was reflected in "Other current assets" on the consolidated balance sheets.
Financial Statement Impact of Derivative Instruments
SCE recognizes realized gains and losses on derivative instruments as purchased power expense and unrealized gains and losses as regulatory assets or liabilities. Both realized and unrealized gains and losses are expected to be recovered from customers and therefore do not affect earnings. Cash flows from derivative activities, including cash collateral, are reported in cash flows from operating activities in SCE's consolidated statements of cash flows.
The following table summarizes the gains/(losses) of SCE's economic hedging activity:
Years ended December 31,
(in millions)202520242023
Realized$(126)$(409)$(14)
Unrealized(174)149 (322)
78
Table of Contents
Notional Volumes of Derivative Instruments
The following table summarizes the notional volumes of derivatives used for SCE's economic hedging activities:
Economic Hedges
Unit of
Measure		December 31,
Commodity20252024
Electricity options, swaps and forwardsGigawatt hours3,2493,295
Natural gas options, swaps and forwardsBillion cubic feet44
Congestion revenue rightsGigawatt hours5,5668,141
Fin Toll arrangementsGigawatt hours228—
Note 7. Revenue
The following table is a summary of SCE's revenue:
Years ended December 31,
(in millions)202520242023
Revenue from contracts with customers
 Commercial$8,215 $8,000 $7,333 
 Residential6,773 7,060 6,421 
 Other3,024 3,335 3,266 
Total revenue from contracts with customer1,2
18,012 18,395 17,020 
Alternative revenue program and other3
1,264 (848)(745)
Total operating revenue$19,276 $17,547 $16,275 
1SCE recorded CPUC revenue based on annual revenue requirement set by a methodology established in the GRC proceedings and FERC revenue authorized through a formula rate. For further information, see Note 1.
2At December 31, 2025 and 2024, SCE's receivables related to contracts from customers were $2.7 billion and $2.9 billion, which included accrued unbilled revenue of $1,236 million and $845 million, respectively.
3Includes differences between revenues from contracts with customers and authorized levels for certain CPUC and FERC revenues.
Deferred Revenue
As of December 31, 2025, SCE has deferred revenue of $341 million related to the sale of the use of transfer capability of West of Devers transmission line, of which $13 million and $328 million are included in "Other current liabilities" and "Other deferred credits and other long-term liabilities," respectively, on SCE's consolidated balance sheets. The deferred revenue is amortized straight-line over a period of 30 years starting 2021.
79
Table of Contents
Note 8. Income Taxes
Current and Deferred Taxes
The components of income tax expense (benefit) by location of taxing jurisdiction are:
Edison InternationalSCE
Years ended December 31,
(in millions)202520242023202520242023
Current:
Federal$— $1 $— $28 $3 $— 
State83 7 — 99 48 5 
83 8 — 127 51 5 
Deferred:
Federal925 59 101976 118 149 
State308 (50)7 337 (49)30 
1,233 9 1081,313 69 179 
Tax Credits
(25)——(25)——
Total$1,291 $17 $108$1,415 $120 $184 
The components of net accumulated deferred income tax liability are:
Edison InternationalSCE
December 31,
(in millions)2025202420252024
Deferred tax assets:
Property$1,005 $943 $992 $929 
Wildfire-related1
339 254 336 251 
Nuclear decommissioning trust assets in excess of nuclear ARO liability455 373 455 373 
Loss and credit carryforwards2
3,246 3,703 1,702 2,242 
Regulatory balances600 610 600 610 
Pension and postretirement benefits other than pensions, net115 117 21 21 
Leases331 335 331 335 
Other199 177 188 167 
Sub-total6,290 6,512 4,625 4,928 
Less: valuation allowance3
14 17 — — 
Total6,276 6,495 4,625 4,928 
Deferred tax liabilities:
Property11,618 11,220 11,598 11,202 
Regulatory balances2,551 1,299 2,551 1,299 
Nuclear decommissioning trust assets455 373 455 373 
Leases331 335 331 335 
Other195 187 162 155 
Total15,150 13,414 15,097 13,364 
Accumulated deferred income tax liability, net4
$8,874 $6,919 $10,472 $8,436 
80
Table of Contents
1Relates to estimated losses accrual for wildfire-related claims, net of expected insurance and regulatory recoveries, and contributions to the Wildfire Fund. For further information, see Note 12 and Note 1.
2As of December 31, 2025, unrecognized tax benefits of $404 million and $326 million for Edison International and SCE, respectively, are presented net against the deferred tax asset for the loss and tax credit carryforwards. As of December 31, 2024, the unrecognized tax benefits netted against deferred tax assets and tax credit carryforwards were $397 million and $327 million for Edison International and SCE, respectively.
3As of December 31, 2025 and 2024, Edison International has recorded $14 million and $17 million valuation allowance on deferred tax assets. The valuation allowance is related to non-California state net operating loss carryforwards which are expected to expire before being utilized.
4Included in "Deferred income taxes and credits" on the consolidated balance sheets.
Net Operating Loss and Tax Credit Carryforwards
The amounts of net operating loss and tax credit carryforwards (after-tax) are as follows:
Edison InternationalSCE
December 31, 2025
(in millions)Loss
Carryforwards		Credit
Carryforwards		Loss
Carryforwards		Credit
Carryforwards
Expire between 2027 to 2030$10 $96 $— $— 
Expire between 2031 to 20451,527 381 725 32 
No expiration date1
1,623 13 1,269 2 
Total$3,160 $490 $1,994 $34 
1Under the Tax Cut and Jobs Act signed into law on December 22, 2017 ("Tax Reform"), net operating losses generated after December 31, 2017 can carryforward indefinitely.
Edison International consolidates for federal income tax purposes, but not for financial accounting purposes, a group of wind projects referred to as "Capistrano Wind." The amount of net operating loss and tax credit carryforwards recognized as part of deferred income taxes includes $106 million and $107 million related to Capistrano Wind for 2025 and 2024, respectively. The tax attributes not utilized as of December 31, 2025 will be available for the Edison International consolidated group to utilize in the future. When the remaining Capistrano tax attributes are used in the future by Edison International, payments will be made to those entities under a tax allocation agreement. Under the tax allocation agreement, Edison International has recorded a corresponding liability as part of other long-term liabilities related to its obligation to make payments to Capistrano Wind when these tax benefits are realized.
81
Table of Contents
Effective Tax Rate
The table below provides a reconciliation of income tax expense computed at the federal statutory income tax rate to the income tax provision:
Edison InternationalSCE
Years ended December 31,
202520242023202520242023
(in millions)Amount%Amount%Amount%Amount%Amount%Amount%
Income from operations before income taxes$5,992 $1,563 $1,515 $6,448 $1,914 $1,781 
Federal Statutory Tax Rate
$1,258 21.0%$328 21.0%$318 21.0%$1,354 21.0%$402 21.0%$374 21.0%
State Income Taxes, Net of Federal Income Tax Effect1
308 5.1%(24)(1.5)%3 0.2%342 5.3%— —%23 1.3%
Tax Credits
(25)(0.4)%——%——%(25)(0.4)%——%——%
Other Adjustments
Property-related
(251)(4.2)%(279)(17.9)%(205)(13.5)%(251)(3.9)%(279)(14.6)%(205)(11.5)%
Other
1 —%(8)(0.5)%(8)(0.6)%(5)(0.1)%(3)(0.1)%(8)(0.5)%
Effective Tax Rate
$1,291 21.5%$17 1.1%$108 7.1%$1,415 21.9%$120 6.3%$184 10.3%
1State taxes in California represents substantially all of the tax effect in this category.
The CPUC requires flow-through ratemaking treatment for the current tax benefit arising from certain property-related and other temporary differences which reverse over time. Flow-through items reduce current authorized revenue requirements in SCE's rate cases and result in a regulatory asset for recovery of deferred income taxes in future periods. The difference between the authorized amounts as determined in SCE's rate cases, adjusted for balancing and memorandum account activities, and the recorded flow-through items also result in increases or decreases in regulatory assets with a corresponding impact on the effective tax rate to the extent that recorded deferred amounts are expected to be recovered in future rates. For further information, see Note 11.
The IRA imposes a 15% corporate alternative minimum tax ("CAMT") on adjusted financial statement income ("AFSI") of corporations with average AFSI exceeding $1.0 billion over the three preceding calendar years. The CAMT was effective beginning January 1, 2023. Based on the current interpretation of the law and historical financial data, Edison International estimates that it will exceed the $1.0 billion threshold and be subject to CAMT on its consolidated federal tax returns beginning in 2026. SCE will also be subject to CAMT in 2026.
Under the IRA, SCE generated investment tax credits of approximately $231 million in 2024 related to utility owned storage projects and $29 million in nuclear production tax credits. In 2025, SCE monetized the majority of these credits for $236 million. SCE expects to pass the proceeds, net of transaction fees, back to customers.
Income taxes Paid/(Refunded)
The components of income tax paid net of (refunds) by location of taxing jurisdiction are:
Edison InternationalSCE
Years ended December 31,
(in millions)202520242023202520242023
Federal$(236)$— $— $(236)$4 $— 
California— 51 — 8 74 — 
SCE makes tax-allocation payments to Edison International under the applicable tax-allocation agreement. It does not make payments to the tax authorities directly. The amount included in 2025 relates to proceeds from the monetization of investment and production tax credits.
82
Table of Contents
Accounting for Uncertainty in Income Taxes
Authoritative guidance related to accounting for uncertainty in income taxes requires an enterprise to recognize, in its financial statements, the best estimate of the impact of a tax position by determining if the weight of available evidence indicates it is more likely than not, based solely on the technical merits, that the position will be sustained upon examination. The guidance requires the disclosure of all unrecognized tax benefits, which includes both the reserves recorded for tax positions on filed tax returns and the unrecognized portion of affirmative claims.
Unrecognized Tax Benefits
The following table provides a reconciliation of unrecognized tax benefits:
Edison InternationalSCE
(in millions)202520242023202520242023
Balance at January 1,$463 $430 $646 $457 $418 $374 
Tax positions taken during the current year:
Increases50 66 65 50 66 65 
Tax positions taken during a prior year:
Increases— 1 13 — — 4 
Decreases1
(30)(34)(294)(30)(27)(25)
Balance at December 31,$483 $463 $430 $477 $457 $418 
1The Edison International decrease in 2023 was mainly related to a write-off of a reserve for a claim related to the Edison Mission Energy bankruptcy.
As of December 31, 2025, if recognized, $70 million of unrecognized tax benefits would impact Edison International's effective tax rate and $64 million of the unrecognized tax benefits would impact SCE's effective tax rate.
Tax Disputes
Tax years that remain open for examination by the Internal Revenue Service and Franchise Tax Board are 2022 – 2024 and 2013 – 2018 & 2021 - 2024, respectively.
Accrued Interest and Penalties
The total amount of accrued interest and penalties related to unrecognized tax benefits are:
Edison InternationalSCE
December 31,
(in millions)2025202420252024
Accrued interest and penalties$2 $— $42 $36 
The net after-tax interest and penalties recognized in income tax expense are:
Edison InternationalSCE
Years ended December 31,
(in millions)202520242023202520242023
Net after-tax interest and penalties tax expense$2$—$—$4$7$4
83
Table of Contents
Note 9. Compensation and Benefit Plans
Employee Savings Plan
The 401(k) defined contribution savings plan is designed to supplement employees' retirement income. The employer contributions were as follows:
Edison
International		SCE
(in millions)Years ended December 31,
2025$144 $143 
2024136 134 
2023121 119 
Pension Plans and Postretirement Benefits Other Than Pensions
Pension Plans
Noncontributory defined benefit pension plans (some with cash balance features) cover most employees meeting minimum service requirements. Employees hired by the participating companies on or after December 31, 2017 are no longer eligible to participate in the pension plans. In lieu of that, additional non-contributory employer contributions are deposited into the Edison 401(k) Savings Plan. SCE recognizes pension expense for its nonexecutive plan as calculated by the actuarial method used for ratemaking. The expected contributions (all by the employer) for Edison International and SCE are approximately $50 million and $21 million, respectively, for the year ending December 31, 2026. The majority of annual contributions made by SCE to its pension plans are anticipated to be recovered through CPUC-approved regulatory mechanisms.
The funded position of Edison International's pension is sensitive to changes in market conditions. Changes in overall interest rate levels significantly affect the company's liabilities, while assets held in the various trusts established to fund Edison International's pension are affected by movements in the equity and bond markets. Due to SCE's regulatory recovery treatment, unrealized losses equal to the unfunded status are recorded to a regulatory asset and unrealized gains equal to the funded status are recorded to a regulatory liability. See Note 11 for further information.
84
Table of Contents
Information on pension plan assets and benefit obligations is shown below.
Edison InternationalSCE
Years ended December 31,
(in millions)2025202420252024
Change in projected benefit obligation
Projected benefit obligation at beginning of year$3,636 $3,647 $3,289 $3,278 
Service cost94 103 90 99 
Interest cost193 175 174 157 
Actuarial loss (gain)97 (59)94 (47)
Benefits paid(315)(230)(285)(198)
Projected benefit obligation at end of year$3,705 $3,636 $3,362 $3,289 
Change in plan assets
Fair value of plan assets at beginning of year$3,608 $3,609 $3,416 $3,415 
Actual return on plan assets389 192 368 182 
Employer contributions38 37 21 17 
Benefits paid(315)(230)(285)(198)
Fair value of plan assets at end of year3,720 3,608 3,520 3,416 
Overfunded/(Underfunded) status at end of year$15 $(28)$158 $127 
Amounts recognized in the consolidated balance sheets consist of 1:
Long-term assets$207 $166 $168 $137 
Current liabilities(28)(27)(1)(1)
Long-term liabilities(164)(167)(9)(9)
$15 $(28)$158 $127 
Amounts recognized in accumulated other comprehensive loss (income) consist of:
Net loss
$2 $8 $17 $13 
Amounts recognized as a regulatory liability(175)(146)(158)(133)
Accumulated benefit obligation at end of year$3,502 $3,508 $3,171 $3,172 
Pension plans with plan assets in excess of an accumulated benefit obligation:
Projected benefit obligation3,705 3,636 3,362 3,289 
Accumulated benefit obligation3,502 3,508 3,171 3,172 
Fair value of plan assets3,720 3,608 3,520 3,416 
Weighted average assumptions used to determine obligations at end of year:
Discount rate5.44%5.56%5.44%5.56%
Rate of compensation increase4.00%4.00%4.00%4.00%
1The SCE liability excludes a long-term payable due to Edison International Parent of $89 million and $88 million at December 31, 2025 and 2024, respectively, related to certain SCE postretirement benefit obligations transferred to Edison International Parent.
For Edison International and SCE, respectively, the 2025 actuarial loss are primarily related to $46 million and $43 million from a decrease of 12 basis points in the discount rate (from 5.56% as of December 31, 2024 to 5.44% as of December 31, 2025) and change in other actuarial assumptions. For Edison International and SCE, respectively, the 2024 actuarial gain are primarily related to $159 million and $146 million from an increase of 52 basis points in the discount rate (from 5.04% as of December 31, 2023 to 5.56% as of December 31, 2024).
85
Table of Contents
Net periodic pension expense components are:
Edison InternationalSCE
Years ended December 31,
(in millions)202520242023202520242023
Service cost$94 $103 $101 $91 $101 $99 
Non-service cost (benefit)
Interest cost193 175 180 179 162 166 
Expected return on plan assets(234)(232)(214)(221)(219)(202)
Amortization of net loss2 4 3 1 2 2 
Regulatory adjustment(25)(23)(47)(24)(22)(47)
Total non-service benefit1
(64)(76)(78)(65)(77)(81)
Total expense$30 $27 $23 $26 $24 $18 
1Included in "Other income" on Edison International's and SCE's consolidated income statements. For further details, see Note 15.
Other changes in pension plan assets and benefit obligations recognized in other comprehensive income:
Edison InternationalSCE
Years ended December 31,
(in millions)202520242023202520242023
Net (gain) loss$(4)$(9)$6 $5 $(2)$6 
Amortization of net gain(2)(4)(2)(1)(2)(2)
Total (gain) loss recognized in other comprehensive income(6)(13)4 4 (4)4 
Total recognized in expense and other comprehensive income$24 $14 $27 $30 $20 $22 
In accordance with authoritative guidance on rate-regulated enterprises, SCE records amortization of net gains and losses into regulatory assets and liabilities instead of charges and credits to other comprehensive income for the portion of SCE's postretirement benefit plans that are recoverable in utility rates.
Edison International and SCE used the following weighted average assumptions to determine pension expense:
Years ended December 31,
202520242023
Discount rate5.56 %5.04 %5.36 %
Rate of compensation increase4.00 %4.00 %4.00 %
Expected long-term return on plan assets6.75 %6.75 %6.50 %
Interest crediting rate for cash balance account
6.06 %5.54 %5.86 %
The following benefit payments, which reflect service rendered and expected future service, are expected to be paid:
(in millions)Edison
International		SCE
2026$263$224
2027262229
2028270238
2029271240
2030281250
2031 – 20351,3971,268
86
Table of Contents
PBOP(s)
Employees hired prior to December 31, 2017 who retire at or after age 55 with at least 10 years of service may be eligible for postretirement healthcare benefits. Eligibility for a company contribution toward the cost of these benefits in retirement depends on a number of factors, including the employee's years of service, age, hire date, and retirement date. Employees hired on or after December 31, 2017 are no longer eligible for retiree healthcare benefits. In lieu of those benefits, Edison International will provide a health reimbursement account of $200 per month available only after meeting certain age and service year requirements. Under the terms of the Edison International Welfare Benefit Plan ("PBOP Plan"), each participating employer (Edison International or its participating subsidiaries) is responsible for the costs and expenses of PBOP Plan benefits with respect to its employees and former employees that exceed the participants' share of contributions. A participating employer may terminate the PBOP Plan benefits with respect to its employees and former employees, as may SCE (as PBOP Plan sponsor), and, accordingly, the participants' PBOP Plan benefits are not vested benefits.
There are no expected contributions for PBOP benefits for the year ended December 31, 2026. Annual contributions related to SCE employees made to SCE plans are anticipated to be recovered through CPUC-approved regulatory mechanisms and are expected to be, at a minimum, equal to the total annual expense for these plans.
SCE has three voluntary employees' beneficiary association trusts ("VEBA Trusts") that can only be used to pay for retiree health care benefits of SCE and its subsidiaries. Once funded into the VEBA Trusts, neither SCE nor Edison International can subsequently recover the remaining amounts in the VEBA Trusts. Participants of the PBOP Plan do not have a beneficial interest in the VEBA Trusts. The VEBA Trust assets are sensitive to changes in market conditions. Changes in overall interest rate levels significantly affect the company's liabilities, while assets held in the various trusts established to fund Edison International's other postretirement benefits are affected by movements in the equity and bond markets. Due to SCE's regulatory recovery treatment, the funded status is offset by a regulatory liability.
87
Table of Contents
Information on PBOP Plan assets and benefit obligations is shown below:
Edison InternationalSCE
Years ended December 31,
(in millions)2025202420252024
Change in benefit obligation
Benefit obligation at beginning of year$741 $773 $737 $769 
Service cost13 14 13 14 
Interest cost40 38 40 38 
Change in plan provisions— 23 — 23 
Actuarial loss (gain)3 (34)3 (34)
Plan participants' contributions26 26 26 26 
Benefits paid(74)(99)(74)(99)
Benefit obligation at end of year$749 $741 $745 $737 
Change in plan assets
Fair value of plan assets at beginning of year$2,281 $2,275 $2,281 $2,275 
Actual return on assets177 78 177 78 
Employer (withdrawals) contributions(11)1 (11)1 
Plan participants' contributions27 26 27 26 
Benefits paid(74)(99)(74)(99)
Fair value of plan assets at end of year2,400 2,281 2,400 2,281 
Overfunded status at end of year$1,651 $1,540 $1,655 $1,544 
Amounts recognized in the consolidated balance sheets consist of:
Long-term assets$1,655 $1,544 $1,655 $1,544 
Current liabilities— (1)— — 
Long-term liabilities(4)(3)— — 
$1,651 $1,540 $1,655 $1,544 
Amounts recognized in accumulated other comprehensive loss (income) consist of:
Net gain$(4)$(4)$— $— 
Amounts recognized as a regulatory liability(1,655)(1,544)(1,655)(1,544)
Weighted average assumptions used to determine obligations at end of year:
Discount rate5.40 %5.60 %5.40 %5.60 %
Assumed health care cost trend rates:
Rate assumed for following year6.50 %6.25 %6.50 %6.25 %
Ultimate rate5.00 %5.00 %5.00 %5.00 %
Year ultimate rate reached2031202920312029
For both Edison International and SCE, the 2025 actuarial loss was primarily related to a $16 million loss from the change in discount rate, partially offset by a $12 million gain from change in demographic assumptions. For Edison International and SCE, the 2024 actuarial gains are primarily related to $41 million in gains from the change in discount rate.
88
Table of Contents
Net periodic PBOP expense components are:
Edison InternationalSCE
Years ended December 31,
(in millions)202520242023202520242023
Service cost$13 $14 $20 $13 $14 $20 
Non-service cost (benefit)
Interest cost40 38 67 40 38 67 
Expected return on plan assets(107)(113)(107)(107)(113)(107)
Amortization of prior service cost1 (1)(1)1 (1)(1)
Amortization of net gain(83)(95)(50)(82)(95)(50)
Regulatory adjustment124 157 71 124 157 71 
Total non-service benefit1
(25)(14)(20)(24)(14)(20)
Total benefit$(12)$— $— $(11)$— $— 
1Included in "Other income" on Edison International's and SCE's consolidated income statements. For further details, see Note 15.
In accordance with authoritative guidance on rate-regulated enterprises, SCE records amortization of net gains and losses to regulatory assets and liabilities instead of charges and credits to other comprehensive income (loss) for the portion of SCE's postretirement benefit plans that are recoverable in utility rates.
Edison International and SCE used the following weighted average assumptions to determine PBOP expense:
Years ended December 31,
202520242023
Discount rate5.60%5.06%5.43%
Expected long-term return on plan assets4.72%4.88%5.00%
Assumed health care cost trend rates:
Current year6.50%6.50%6.75%
Ultimate rate5.00%5.00%5.00%
Year ultimate rate reached203120292029
The following benefit payments (net of plan participants' contributions) are expected to be paid:
(in millions)Edison
International		SCE
2026$47 $47 
202751 51 
202851 51 
202952 51 
203052 52 
2031 – 2035272 271 
Plan Assets
Description of Pension and Postretirement Benefits Other than Pensions Investment Strategies
The investment of plan assets is overseen by a fiduciary investment committee. Plan assets are invested using a combination of asset classes and may have active and passive investment strategies within asset classes. Target allocations for 2025 pension plan assets were 60% for fixed income, 24% for global equities, and 16% for opportunistic and/or alternative investments. Target allocations for 2025 PBOP plan assets (except for Represented VEBA which is 93% for fixed income, 6% for global equities, and 1% for opportunistic and/or alternative investments) are 62% for fixed income, 28% for global equities, and 10% for opportunistic and/or alternative investments. Edison International employs multiple investment management firms. Investment managers within each asset class cover a range of investment styles and approaches. Risk is managed through diversification among multiple asset classes, managers, styles and securities. Plan
89
Table of Contents
asset classes and individual manager performances are measured against targets. Edison International also monitors the stability of its investment managers' organizations.
Allowable investment types under CPUC investment guidelines include:
•Global equities: common and preferred stocks, as well as other equity securities, issued by companies of large, medium, and small capitalization domiciled in any country, including the United States and all non‑U.S. markets.
•Fixed income: fixed income securities issued or guaranteed by the United States government, non-United States governments, government agencies and instrumentalities including municipal bonds, mortgage backed securities and corporate debt obligations. A portion of the fixed income positions may be held in debt securities that are below investment grade.
•Opportunistic, alternative and other investments: Opportunistic investments in short to intermediate term market opportunities. Investments may have fixed income and/or equity characteristics and may be either liquid or illiquid. Alternative investments are limited partnerships that invest in non-publicly traded entities. Other investments are diversified among multiple asset classes such as global equity, fixed income currency and commodities markets. Investments are made in liquid or illiquid instruments within and across markets. The investment returns are expected to approximate the plans' expected investment returns.
Asset class portfolio weights are permitted to range within plus or minus 5%. Where approved by the fiduciary investment committee, futures contracts are used for portfolio rebalancing and to reallocate portfolio cash positions. Where authorized, a few of the plans' investment managers employ limited use of derivatives, including futures contracts, options, options on futures and interest rate swaps in place of direct investment in securities to gain efficient exposure to markets. Derivatives are not used to leverage the plans or any portfolios.
Determination of the Expected Long-Term Rate of Return on Assets
The overall expected long-term rate of return on assets assumption is based on the long-term target asset allocation for plan assets and capital markets return forecasts for asset classes employed. A portion of the PBOP trust asset returns is subject to taxation, so the expected long-term rate of return for these assets is determined on an after-tax basis.
Capital Markets Return Forecasts
Edison International's capital markets return forecast methodologies primarily use a combination of historical market data, current market conditions, proprietary forecasting expertise, complex models to develop asset class return forecasts, and a building block approach. The forecasts are developed using variables such as real risk-free interest, inflation and asset class specific risk premiums. For equities, the risk premium is based on an implied average equity risk premium of 4% over cash. The forecasted return on private equity and alternative investments are estimated at a 3% premium above public equity, reflecting a premium for higher volatility and lower liquidity. For fixed income, the risk premium is based on a comprehensive modeling of credit spreads.
Fair Value of Plan Assets
The PBOP Plan and the Southern California Edison Company Retirement Plan Trust assets include investments in equity securities, U.S. treasury securities, other fixed-income securities, common/collective funds, mutual funds, other investment entities, foreign exchange and interest rate contracts, and partnership/joint ventures. Equity securities, U.S. treasury securities, and mutual and money market funds are classified as Level 1 as fair value is determined by observable, unadjusted quoted market prices in active or highly liquid and transparent markets. The fair value of the underlying investments in equity mutual funds are based on stock-exchange prices. The fair value of the underlying investments in fixed-income mutual funds and other fixed income securities including municipal bonds are based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes, issuer spreads, bids, offers, and relevant credit information. Foreign exchange and interest rate contracts are classified as Level 2 because the values are based on observable prices but are not traded on an exchange. Futures contracts trade on an exchange and therefore are classified as Level 1. No investment is classified as Level 3 as of December 31, 2025 and 2024. Common/collective funds and partnerships are measured at fair value using the net asset value per share ("NAV") and have not been classified in the fair value hierarchy. Other investment entities are valued similarly to common/collective funds and are therefore classified as NAV. The Level 1 registered investment companies are either mutual or money market funds. The remaining funds in this category are readily redeemable and classified as NAV and are discussed further in the below pension plan trust investments table's note 8.
Edison International reviews the process/procedures of both the pricing services and the trustee to gain an understanding of the inputs/assumptions and valuation techniques used to price each asset type/class. The trustee and Edison International's validation procedures for pension and PBOP equity and fixed income securities are the same as the nuclear
90
Table of Contents
decommissioning trusts. For further discussion, see Note 4. The values of Level 1 mutual and money market funds are publicly quoted. The trustees obtain the values of common/collective and other investment funds from the fund managers. The values of partnerships are based on partnership valuation statements updated for cash flows. SCE's investment managers corroborate the trustee fair values.
Pension Plan
The following table sets forth the investments for Edison International and SCE that were accounted for at fair value as of December 31, 2025 and 2024, respectively, by asset class and level within the fair value hierarchy:
December 31, 2025
(in millions)Level 1Level 2
NAV1
Total
U.S. government and agency securities2
$209 $340 $— $549 
Corporate stocks3
2 5 — 7 
Corporate bonds4
— 1,151 — 1,151 
Common/collective funds5
— — 671 671 
Partnerships/joint ventures6
— — 1,034 1,034 
Other investment entities7
— — 71 71 
Registered investment companies8
244 — 17 261 
Interest-bearing cash13 — — 13 
Other— 63 — 63 
Total$468 $1,559 $1,793 $3,820 
Receivables and payables, net(100)
Combined net plan assets available for benefits3,720 
SCE's share of net plan assets$3,520 
December 31, 2024
(in millions)Level 1Level 2
NAV1
Total
U.S. government and agency securities2
$244 $353 $— $597 
Corporate stocks3
148 4 — 152 
Corporate bonds4
— 1,084 — 1,084 
Common/collective funds5
— — 652 652 
Partnerships/joint ventures6
— — 680 680 
Other investment entities7
— — 58 58 
Registered investment companies8
238 — 142 380 
Interest-bearing cash14 — — 14 
Other— 57 8 65 
Total$644 $1,498 $1,540 $3,682 
Receivables and payables, net(74)
Combined net plan assets available for benefits3,608 
SCE's share of net plan assets $3,416 
1These investments are measured at fair value using the net asset value per share practical expedient and have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the net plan assets available for benefits.
2Level 1 U.S. government and agency securities are U.S. treasury bonds and notes. Level 2 primarily relates to the Federal National Mortgage Association and the Federal Home Loan Mortgage Corporation.
3Corporate stocks are diversified. At December 31, 2025, all equity holdings are under commingled funds. At December 31, 2024, performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes (33%) and Morgan Stanley Capital International (MSCI) index (67%).
91
Table of Contents
4Corporate bonds are diversified. At December 31, 2025 and 2024, respectively, this category includes $56 million and $77 million for collateralized mortgage obligations and other asset backed securities.
5At December 31, 2025, 79% of the common/collective assets are invested in equity index funds that seek to track performance of the MSCI All Country World Index ex-US, and 17% are invested in non‑index equity funds seeking to outperform the MSCI ACWI IMI through an active quantitative strategy. At December 31, 2024, 38% of the common/collective assets are invested in equity index funds that seek to track performance of the Standard and Poor's 500 Index, 38% are in index funds which seek to track performance in the MSCI All Country World Index ex-US and 19% are in a non-index U.S. equity fund, which is actively managed.
6At December 31, 2025 and 2024, respectively, 48% and 69% are invested in private equity funds with investment strategies that include branded consumer products and clean technology companies, 27% and 5% are invested in a broad range of financial assets in all global markets, 14% and 16% are invested in ABS including distressed mortgages and commercial and residential loans, and 10% and 9% are invested in fixed income securities.
7At December 31, 2025 and 2024, respectively, 76% and 70% are invested in domestic mortgage backed securities and 24% and 30% in high yield debt securities.
8At December 31, 2025 and 2024, respectively, 83% and 56% are invested in Level 1 corporate bond funds and 17% and 10% in a fixed income fund used for cash management. At December 31, 2024, 34% was also invested in a US equity fund.
At both December 31, 2025 and 2024, approximately 64% of the publicly traded equity investments, including equities in the common/collective funds, were located in the United States.
Postretirement Benefits Other than Pensions
The following table sets forth the VEBA Trust assets for Edison International and SCE that were accounted for at fair value as of December 31, 2025 and 2024, respectively, by asset class and level within the fair value hierarchy:
December 31, 2025
(in millions)Level 1Level 2
NAV1
Total
U.S. government and agency securities2
$535 $44 $— $579 
Corporate stocks3
78 1 — 79 
Corporate notes and bonds4
— 1,170 — 1,170 
Common/collective funds5
— — 241 241 
Partnerships6
— — 175 175 
Registered investment companies7
46 — — 46 
Interest bearing cash— 20 — 20 
Other8
(1)131 — 130 
Total$658 $1,366 $416 $2,440 
Receivables and payables, net(40)
Net plan assets available for benefits$2,400 
December 31, 2024
(in millions)Level 1Level 2
NAV1
Total
U.S. government and agency securities2
$489 $51 $— $540 
Corporate stocks3
81 2 — 83 
Corporate notes and bonds4
— 1,126 — 1,126 
Common/collective funds5
— — 235 235 
Partnerships6
— — 119 119 
Registered investment companies7
52 — — 52 
Interest bearing cash— 45 — 45 
Other8
— 95 — 95 
Total$622 $1,319 $354 $2,295 
Receivables and payables, net(14)
Net plan assets available for benefits$2,281 
92
Table of Contents
1These investments are measured at fair value using the net asset value per share practical expedient and have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the net plan assets available for benefits.
2Level 1 U.S. government and agency securities are U.S. treasury bonds and notes. Level 2 primarily relates to the Federal Home Loan Mortgage Corporation and the Federal National Mortgage Association.
3Corporate stock performance for actively managed separate accounts is primarily benchmarked against the Russell Indexes (71% and 78% at December 31, 2025 and 2024, respectively) and the MSCI All Country World Index (29% and 22% at December 31, 2025 and 2024, respectively).
4Corporate notes and bonds are diversified and include approximately $362 million and $343 million for commercial collateralized mortgage obligations and other asset backed securities at December 31, 2025 and 2024, respectively.
5At December 31, 2025, 85% the common/collective assets are invested in index funds which seek to track performance in the MSCI All Country World Investable Market Index, and the remaining assets in this category are primarily invested in fixed income funds. At December 31, 2024, 47% of the common/collective assets are invested in index funds which seek to track performance in the MSCI All Country World Investable Market Index, and 41% are invested in a non-index U.S. equity fund which is actively managed. The remaining assets in this category are primarily invested in emerging market fund and fixed income funds.
6At December 31, 2025 and 2024, respectively, 58% and 71% of the partnerships are invested in private equity and venture capital funds. Investment strategies for these funds include branded consumer products, clean and information technology and healthcare. Of the remaining partnerships category, 9% and 22% are invested in asset backed securities including distressed mortgages, distressed companies and commercial and residential loans and debt and equity of banks; 33% and 7% are invested in a broad range of financial assets in all global markets.
7At December 31, 2025 and 2024, respectively, registered investment companies were primarily invested in a money market fund (63% and 73%) and exchange rate traded funds which seek to track performance of MSCI Emerging Market Index, Russell 2000 Index and international small cap equities (37% and 27%).
8Other includes $61 million and $52 million of municipal securities at December 31, 2025 and 2024, respectively.
At December 31, 2025 and 2024, approximately 71% and 78% of the publicly traded equity investments, including equities in the common/collective funds, were located in the United States.
Stock-Based Compensation
Edison International maintains a shareholder-approved incentive plan (the "2007 Performance Incentive Plan") that includes stock-based compensation. The maximum number of shares of Edison International's common stock authorized to be issued or transferred pursuant to awards under the 2007 Performance Incentive Plan, as amended, is approximately 71 million shares. As of December 31, 2025, Edison International had approximately 25 million shares remaining available for new award grants under its stock-based compensation plans.
The following table summarizes total expense and tax benefits associated with stock-based compensation:
Edison InternationalSCE
Years ended December 31,
(in millions)202520242023202520242023
Stock-based compensation expense1:
Stock options$11$13 $12 $6$7 $6 
Performance shares2321 15 1010 8 
Restricted stock units2121 17 1415 12 
Other22 2 —— — 
Total stock-based compensation expense$57$57 $46 $30$32 $26 
Income tax benefits related to stock-based compensation expense$13$23 $7 $7$14 $5 
1Reflected in "Operation and maintenance" on Edison International's and SCE's consolidated statements of income.
Stock Options
Under the 2007 Performance Incentive Plan, Edison International has granted stock options at exercise prices equal to the closing price at the grant date. Edison International may grant stock options and other awards related to, or with a value derived from, its common stock to directors and certain employees. Options generally expire 10 years after the grant date
93
Table of Contents
and vest over a period of three or four years of continuous service in equal annual increments, except for awards granted to retirement-eligible participants, which vest on an accelerated basis.
The fair value for each option granted was determined as of the grant date using the Black-Scholes option-pricing model. The Black-Scholes option-pricing model requires various assumptions noted in the following table:
Years ended December 31,
202520242023
Expected terms (in years)4.94.74.8
Risk-free interest rate
3.8% - 4.1%
3.7% - 4.5%
3.6% - 4.7%
Expected dividend yield
5.6% - 6.4%
3.6% - 4.7%
4.2% - 4.7%
Weighted average expected dividend yield6.0%4.7%4.2%
Expected volatility
25.3% - 26.0%
23.6% - 30.4%
29.0% - 29.6%
Weighted average volatility25.9%30.3%29.1%
The expected term represents the period of time for which the options are expected to be outstanding and is primarily based on historical exercise and post-vesting cancellation experience and stock price history. The risk-free interest rate for periods within the contractual life of the option is based on a zero-coupon U.S. Treasury STRIPS (separate trading of registered interest and principal of securities) whose maturity corresponds to the option's expected term on the measurement date. Expected volatility is based on the historical volatility of Edison International's common stock for the length of the option's expected term. The volatility period used was 59 months, 56 months, and 58 months at December 31, 2025, 2024, and 2023, respectively.
The following is a summary of the status of Edison International's stock options:
Weighted Average
SharesExercise
Price		Remaining
Contractual
Term (years)		Aggregate
Intrinsic Value
(in millions)
Edison International:
Outstanding at December 31, 20248,643,575$64.33 
Granted1,603,11055.04 
Forfeited or expired(124,464)61.60 
Exercised1
(237,700)62.29 
Outstanding at December 31, 20259,884,52162.91 4.86
Exercisable and expected to vest at December 31, 20259,696,95462.98 4.79$16 
Exercisable at December 31, 20257,646,255$64.21 3.77$9 
SCE:
Outstanding at December 31, 20243,606,450$64.18 
Granted818,34855.23 
Forfeited or expired(124,464)61.60 
Exercised1
(99,545)59.68 
Affiliate transfers, net(57,730)64.18 
Outstanding at December 31, 20254,143,05962.59 5.15
Exercisable and expected to vest at December 31,20254,052,11062.66 5.08$7 
Exercisable at December 31, 20253,055,865$64.03 3.92$4 
1Edison International and SCE recognized tax benefits of $1 million and zero million, respectively, from stock options exercised in 2025.
94
Table of Contents
At December 31, 2025, total unrecognized compensation cost related to stock options and the weighted average period the cost is expected to be recognized are as follows:
Edison InternationalSCE
Unrecognized compensation cost, net of expected forfeitures (in millions)$8 $5 
Weighted average period (in years)1.21.3
The following is a summary of supplemental data on stock options:
Edison InternationalSCE
Years ended December 31,
(in millions, except per award amounts)202520242023202520242023
Weighted average grant date fair value per option granted$7.79 $13.32 $12.69 $7.85 $13.36 $12.71 
Fair value of options vested13 14 8 6 7 7 
Value of options exercised3 45 14 1 25 11 
Performance Shares
A target number of contingent performance shares were awarded to executives in 2025, 2024, and 2023 and vest as of December 31, 2027, 2026, and 2025, respectively. The vesting of the grants is dependent upon market and financial performance and service conditions as defined in the grants for each of the years. The number of performance shares earned from each year's grants could range from zero to twice the target number (plus additional units credited as dividend equivalents).
The fair value of market condition performance shares is determined using a Monte Carlo simulation valuation model for the total shareholder return. The fair value of financial performance condition performance shares is determined (i) at grant as the target number of shares (which Edison International determined to be the probable outcome) valued at the closing price on the grant date of Edison International common stock and (ii) subsequently using Edison International's earnings per share compared to pre-established targets.
The following is a summary of the status of Edison International's nonvested performance shares:
Equity Awards
SharesWeighted Average
Fair Value
Edison International:
Nonvested at December 31, 2024518,520$74.01
Granted403,99261.87
Forfeited(32,557)69.03
Vested(236,755)76.01
Nonvested at December 31, 2025653,200$66.02
SCE:
Nonvested at December 31, 2024264,974$74.17
Granted206,77962.17
Forfeited(32,557)69.03
Vested(113,249)76.23
Affiliate transfers, net(4,938)74.17
Nonvested at December 31, 2025321,009$66.24
Restricted Stock Units
Restricted stock units were awarded to executives in 2025, 2024, and 2023 and vest and become payable on January 3, 2028, January 4, 2027, and January 2, 2026, respectively. Each restricted stock unit awarded includes a dividend equivalent feature and is a contractual right to receive one share of Edison International common stock, if vesting requirements are
95
Table of Contents
satisfied. The vesting of Edison International's restricted stock units is dependent upon continuous service through the end of the vesting period, except for awards granted to retirement-eligible participants, which vest on an accelerated basis.
The following is a summary of the status of Edison International's nonvested restricted stock units:
Edison InternationalSCE
SharesWeighted Average
Grant Date
Fair Value		SharesWeighted Average
Grant Date
Fair Value
Nonvested at December 31, 2024876,448$65.19 620,727$65.22 
Granted443,08155.14 312,67855.21 
Forfeited(36,319)62.01 (34,094)61.82 
Vested(282,787)63.51 (201,887)63.51 
Affiliate transfers, net—— (2,729)65.22 
Nonvested at December 31, 20251,000,423$57.46 694,695$57.39 
The fair value for each restricted stock unit awarded is determined as the closing price of Edison International common stock on the grant date.
96
Table of Contents
Note 10. Investments
Nuclear Decommissioning Trusts
Future decommissioning costs related to SCE's nuclear assets are expected to be funded from independent decommissioning trusts.
The following table sets forth amortized cost and fair value of the trust investments (see Note 4 for a discussion on fair value of the trust investments):
Amortized CostsFair Values
(in millions)Longest Maturity DatesDecember 31,
2025		December 31,
2024		December 31,
2025		December 31,
2024
Municipal bonds2067$718 $729 $899 $860 
Government and agency securities20741,149 1,201 1,367 1,341 
Corporate bonds2072315 346 380 392 
Short-term investments and receivables/payables1
One-year200 152 (20)62 
Total debt securities and other2,382 2,428 2,626 2,655 
Equity securities1,909 1,631 
Total2
$4,535 $4,286 
1As of December 31, 2025 and 2024, short-term investments included $27 million and $18 million of repurchase agreement payable by financial institutions which earned interest, were fully secured by U.S. Treasury securities, and mature by January 2, 2026 and January 2, 2025, respectively.
2Represents amounts before reduction for deferred tax liabilities on net unrealized gains of $455 million and $373 million as of December 31, 2025 and 2024, respectively.
Trust fund earnings (based on specific identification) increase the trust fund balance and the ARO regulatory liability. Unrealized holding gains, net of losses, were $2.0 billion and $1.7 billion at December 31, 2025 and 2024, respectively.
The following table summarizes the gains and losses for the trust investments:
Years ended December 31,
(in millions)202520242023
Gross realized gains$89 $326 $323 
Gross realized losses(14)(24)(73)
Net unrealized gains (losses) for equity securities256 (19)103 
Due to regulatory mechanisms, changes in the assets of the trusts from income or loss items do not materially affect earnings.
Note 11. Regulatory Assets and Liabilities
Included in SCE's regulatory assets and liabilities are regulatory balancing accounts. CPUC-authorized balancing account mechanisms require SCE to refund or recover any differences between forecasted and actual costs. The CPUC has authorized balancing accounts for specified costs or programs such as fuel, purchased power, demand-side management programs, wildfire related costs, nuclear decommissioning and public purpose programs. Certain of these balancing accounts include a return on rate base of 7.66% and 7.87% in 2025 and 2024, respectively. The CPUC authorizes the use of a balancing account to recover from or refund to customers differences in revenue resulting from actual and forecasted electricity sales.
Amounts included in regulatory assets and liabilities are generally recorded with corresponding offsets to the applicable income statement accounts.
97
Table of Contents
Regulatory Assets
SCE's regulatory assets included on the consolidated balance sheets are:
December 31,
(in millions)20252024
Current:
Regulatory balancing and memorandum accounts$3,246 $2,723 
Other44 25 
Total current3,290 2,748 
Long-term:
Deferred income taxes6,427 5,982 
Unamortized investments, net of accumulated amortization126 115 
Unamortized losses on reacquired debt79 88 
Regulatory balancing and memorandum accounts2,843 867 
Environmental remediation213 222 
Recovery assets3,092 1,512 
Other180 100 
Total long-term12,960 8,886 
Total regulatory assets$16,250 $11,634 
In accordance with the accounting standards applicable to rate-regulated enterprises, SCE defers costs as regulatory assets that are probable of future recovery from customers and has recorded regulatory assets for these incremental costs at December 31, 2025. While SCE believes such costs are probable of future recovery, there is no assurance that SCE will collect all amounts currently deferred as regulatory assets.
SCE's regulatory assets related to deferred income taxes represent tax benefits passed through to customers. The CPUC requires SCE to flow through certain deferred income tax benefits to customers by reducing electricity rates, thereby deferring recovery of such amounts to future periods. Based on current regulatory ratemaking and income tax laws, SCE expects to recover its regulatory assets related to deferred income taxes over the life of the assets that give rise to the accumulated deferred income taxes, approximately from 1 to 60 years. For further information, see Note 8.
SCE has long-term unamortized investments which include nuclear assets related to Palo Verde and the beyond the meter program. Nuclear assets related to Palo Verde and the beyond the meter program are expected to be recovered by 2046 and 2031, respectively, and both earned returns of 7.66% and 7.87% in 2025 and 2024, respectively.
SCE's net regulatory asset related to its unamortized losses on reacquired debt will be recovered over the original amortization period of the reacquired debt over periods ranging from 10 to 40 years or the life of the new issuance if the debt is refunded or refinanced.
SCE's regulatory assets related to environmental remediation represent a portion of the costs incurred at certain sites that SCE is allowed to recover through customer rates. See "Environmental Remediation" discussed in Note 12.
Recovery assets represent the balance associated with the Recovery Property and prudently incurred financing costs securitized with issuance of the associated bond. The recovery period is until 2050, when the bonds and interest are paid in full. For further details, see Note 3.
98
Table of Contents
Regulatory Liabilities
SCE's regulatory liabilities included on the consolidated balance sheets are:
December 31,
(in millions)20252024
Current:
Regulatory balancing and memorandum accounts$1,139 $1,144 
Energy derivatives— 165 
Other19 38 
Total current1,158 1,347 
Long-term:
Costs of removal2,737 2,520 
Deferred income taxes2,126 2,163 
Recoveries in excess of ARO liabilities2,057 1,748 
Regulatory balancing and memorandum accounts1,842 2,023 
Pension and other postretirement benefits1,829 1,690 
Other36 15 
Total long-term10,627 10,159 
Total regulatory liabilities$11,785 $11,506 
SCE's regulatory liabilities related to energy derivatives are primarily an offset to unrealized gains on derivatives.
SCE's regulatory liabilities related to costs of removal represent differences between asset removal costs recorded and amounts collected in rates for those costs.
SCE's regulatory liabilities include excess deferred income taxes resulting from statutory income tax rate changes. The regulatory liabilities are generally expected to be refunded to customers over the lives of the assets and liabilities that gave rise to the deferred income taxes.
SCE's regulatory liabilities related to recoveries in excess of ARO liabilities represent the cumulative differences between ARO obligations and amounts collected in rates primarily for the decommissioning of SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 10 for further discussion.
SCE's regulatory liabilities related to pension and other post-retirement plans represent the net overfunded status of the plans. This amount is expected to be amortized over the expected future service of the employees (subject to regulatory adjustment) or refunded to ratepayers at the termination or completion of the plan. See "Pension Plans and Postretirement Benefits Other than Pensions" discussion in Note 9.
Net Regulatory Balancing and Memorandum Accounts
Balancing accounts track amounts that the CPUC or FERC have authorized for recovery. Balancing account over and under collections represent differences between cash collected in current rates for specified forecasted costs and such costs that are actually incurred. Undercollections are recorded as regulatory balancing account assets. Overcollections are recorded as regulatory balancing account liabilities. With some exceptions, SCE seeks to adjust rates on an annual basis or at other designated times to recover or refund the balances recorded in its balancing accounts. Memorandum accounts are authorized to track costs for potential future recovery.
Regulatory balancing and memorandum accounts that SCE does not expect to collect or refund in the next 12 months are reflected in the long-term section of the consolidated balance sheets. Regulatory balancing and memorandum accounts that do not have the right of offset are presented gross in the consolidated balance sheets. Under and over collections in balancing accounts and amounts recorded in memorandum accounts typically accrue interest based on a three-month commercial paper rate published by the Federal Reserve.
The following table summarizes the significant components of regulatory balancing and memorandum accounts included in the above tables of regulatory assets and liabilities:
99
Table of Contents
December 31,
(in millions)20252024
Asset (liability)
Energy procurement related costs$589 $(97)
Public purpose and energy efficiency(2,054)(1,708)
GRC related balancing accounts1
1,945 976 
FERC related balancing accounts204 125 
Wildfire risk mitigation and insurance2
289 741 
Wildfire and drought restoration3
215 238 
Woolsey Settlement cost recovery4
1,766 — 
Tax accounting memorandum account(3)(40)
Other157 188 
Assets, net of liabilities$3,108 $423 
1The GRC related balancing accounts primarily consist of the base revenue requirement balancing account ("BRRBA"), the vegetation management balancing account ("VMBA"), the Wildfire Risk Mitigation balancing account ("WRMBA") and the risk management balancing account ("RMBA").
The 2025 GRC decision approved the establishment of a two-way Grid Hardening Balancing Account to track the difference between the actual Targeted Undergrounding Program and Rapid Earth Fault Current Limiter costs up to the approved mile limit and the authorized amounts, with spending in excess of 110% of authorized amounts subject to reasonableness review. Additionally, the final decision authorized SCE to establish a memorandum account to track and record capital expenditures above the amounts authorized to support SCE's grid readiness for future transportation electrification demand, with cost recovery subject to reasonableness review.
2The wildfire risk mitigation and insurance regulatory assets represent wildfire-related costs that are probable of future recovery from customers, subject to a reasonableness review. The Wildfire Expense Memorandum Account ("WEMA") is used to track incremental wildfire insurance costs and uninsured wildfire-related financing, legal and claim costs related to the Other Wildfire Events that SCE believes are probable of recovery. See Note 12 for further details. The Wildfire Mitigation Plan Memorandum Account is used to track costs incurred to implement SCE's wildfire mitigation plan that are not currently reflected in SCE's revenue requirements. The Fire Risk Mitigation Memorandum Account is used to track costs related to the reduction of fire risk that are incremental to costs approved for recovery in SCE's GRCs that are not tracked in any other wildfire-related memorandum account.
3The wildfire and drought restoration regulatory assets represent restoration costs that are recorded in a Catastrophic Event Memorandum Account.
4Cost recoveries authorized under the Woolsey Settlement Agreement. See Note 12 for more information.
100
Table of Contents
Note 12. Commitments and Contingencies
Power Purchase Agreements
SCE entered into various agreements to purchase power, electric capacity and other energy products. At December 31, 2025, the undiscounted future expected minimum payments for the SCE PPAs (primarily related to renewable energy contracts), which were approved by the CPUC and met other critical contract provisions (including completion of major milestones for construction), were as follows:
(in millions)Total
2026$3,244 
20273,098 
20282,603 
20292,604 
20302,550 
Thereafter15,709 
Total future commitments1
$29,808 
1Certain power purchase agreements are treated as operating leases. For further discussion, see Note 13.
Additionally, as of December 31, 2025, SCE has executed contracts that have not met the critical contract provisions that would increase contractual obligations by $44 million in 2026, $172 million in 2027, $368 million in 2028, $534 million in 2029, $597 million in 2030, and $7,237 million thereafter, if all critical contract provisions are completed.
Costs incurred for PPAs were $4.0 billion in 2025, $4.0 billion in 2024 and $4.5 billion in 2023, which include costs associated with contracts with terms of less than one year.
Other Commitments
The following summarizes the estimated minimum future commitments for SCE's other commitments:
(in millions)20262027202820292030ThereafterTotal
Other contractual obligations$74$73$68$56$34$133$438
Costs incurred for other commitments were $65 million in 2025, $65 million in 2024 and $60 million in 2023. Other commitments include fuel supply contracts for Palo Verde which require payment only if the fuel is made available for purchase. Also included are commitments related to maintaining reliability and expanding SCE's transmission and distribution system.
The table above does not include asset retirement obligations, which are discussed in Note 1.
Indemnities
Edison International and SCE have agreed to provide indemnifications through contracts entered into in the normal course of business. These are primarily indemnifications against adverse litigation outcomes in connection with underwriting agreements, indemnities for specified environmental liabilities and income taxes or other contractual arrangements. Edison International's and SCE's obligations under these agreements may or may not be limited in terms of time and/or amount, and in some instances Edison International and SCE may have recourse against third parties. Edison International and SCE have not recorded a liability related to these indemnities. The overall maximum amount of the obligations under these indemnifications cannot be reasonably estimated.
Contingencies
In addition to the matters disclosed in these Notes, Edison International and SCE are involved in other legal, tax, and regulatory proceedings before various courts and governmental agencies regarding matters arising in the ordinary course of business, all of which are subject to uncertainties. Edison International and SCE believe the outcome of each of these other proceedings will not materially affect its financial position, results of operations and cash flows. Legal costs expected to be incurred by Edison International and SCE in connection with loss contingencies are expensed as incurred.
101
Table of Contents
Southern California Wildfires and Mudslides
Unprecedented weather conditions in California due to climate change and greater concentrations of residents in high-fire risk areas, among other things, have contributed to wildfires, including those where SCE's equipment has been alleged to be associated with the fire's ignition, that have caused loss of life and substantial damage in SCE's service area.
Numerous claims related to wildfire events have been initiated against SCE and Edison International. Edison International and SCE have, or may, incur material losses in connection with the 2017/2018 Wildfire/Mudslide Events, the Other Wildfire Events that are described below, and the January 2025 Eaton Fire. Of the Other Wildfire Events described below, only the 2017 Creek Fire ignited prior to the adoption of AB 1054 in July 2019. SCE's equipment has been, and may further be, alleged to be associated with other wildfires that have originated in Southern California, and SCE's service area remains susceptible to additional wildfire activity.
Liability Overview
The extent of legal liability for wildfire-related damages in actions against utilities depends on a number of factors, including whether the utility substantially caused or contributed to the damages and whether parties seeking recovery of damages will be required to show negligence in addition to causation. California courts have previously found utilities to be strictly liable for property damage along with associated interest and attorneys' fees, regardless of fault, by applying the theory of inverse condemnation when a utility's facilities were determined to be a substantial cause of a wildfire that caused the property damage. If inverse condemnation is held to be inapplicable to SCE in connection with a wildfire, SCE still could be held liable for property damages and associated interest if the property damages were found to have been proximately caused by SCE's negligence. If SCE were to be found negligent, SCE could also be held liable for, among other things, fire suppression costs, business interruption losses, evacuation costs, clean-up costs, medical expenses, and personal injury/wrongful death claims, including claims for non-economic damages. Additionally, SCE could potentially be subject to fines and penalties for alleged violations of CPUC rules and state laws investigated in connection with the ignition of a wildfire.
While investigations into the cause of a wildfire event are conducted by one or more fire agencies, fire agency findings do not determine legal causation of or assign legal liability for a wildfire event. Final determinations of legal causation and liability for wildfire events, including determinations of whether SCE was negligent, would only be made during lengthy and complex litigation processes, and settlements may be reached before determinations of legal liability are ever made. Even when investigations are still pending or legal liability is disputed, an assessment of likely outcomes, including through future settlement of claims, may require estimated losses to be accrued under accounting standards.
Estimates and Assumptions
Each reporting period, management reviews its loss estimates for remaining alleged and potential claims related to wildfire events. The process for estimating losses associated with alleged and potential wildfire related claims requires management to exercise significant judgment based on a number of assumptions and subjective factors, including, but not limited to: volume of claims, damages asserted and associated loss, opinions of counsel regarding litigation risk, the status of and developments in the course of litigation, prior experience litigating and settling wildfire litigation claims, the amount of insurance that may offset losses, and estimating contributory liabilities from third parties who may be responsible for portions of loss.
Estimated losses for wildfire litigation are based on a number of assumptions and are subject to change as additional information becomes available. As additional information becomes available, management's estimates and assumptions regarding the causes and financial impact of wildfire events may change. Actual losses incurred may be higher or lower than estimated based on several factors, including the uncertainty in estimating damages that have been or may be alleged and uncertainty in estimating settlement outcomes. For instance, SCE receives additional information with respect to damages claimed as claims mediation and trial processes progress. Other factors that can cause actual losses incurred to be higher or lower than estimated include the ability to reach settlements and the outcomes of settlements reached through claims mediation processes, uncertainties related to the impact of outcomes of wildfire litigation against other parties and increasingly negative jury sentiments in general litigation, uncertainties related to the sufficiency of insurance held by plaintiffs and potential plaintiffs, uncertainties related to litigation processes, including whether plaintiffs will ultimately pursue claims, uncertainty as to the legal and factual determinations to be made during litigation, including uncertainty as to the contributing causes of wildfire events, and the uncertainty as to how these factors impact future settlements.
Litigation
2017/2018 Wildfire/Mudslide Events
Wildfires in SCE's service area in December 2017 and November 2018 caused loss of life, substantial damage to both residential and business properties, and service outages for SCE customers. The investigating government agencies, the
102
Table of Contents
Ventura County Fire Department ("VCFD") and CAL FIRE, have determined that the largest of the 2017 fires in SCE's service area originated on December 4, 2017, in the Anlauf Canyon area of Ventura County, followed shortly thereafter by a second fire that originated near Koenigstein Road in the City of Santa Paula. According to CAL FIRE, the Thomas and Koenigstein Fires, collectively, burned over 280,000 acres, destroyed or damaged an estimated 1,343 structures and resulted in two confirmed fatalities. The largest of the November 2018 fires in SCE's service area, the Woolsey Fire, originated in Ventura County. According to CAL FIRE, the Woolsey Fire burned almost 100,000 acres, destroyed an estimated 1,643 structures, damaged an estimated 364 structures and resulted in three confirmed fatalities. Four additional fatalities are alleged to have been associated with the Woolsey Fire.
Multiple lawsuits related to the Thomas and Koenigstein Fires and the Woolsey Fire have been initiated against SCE and Edison International. Some of the Thomas and Koenigstein Fires lawsuits claim that SCE and Edison International have responsibility for the damages caused by debris flows and flooding in Montecito and surrounding areas in January 2018 based on a theory alleging that SCE has responsibility for the Thomas and/or Koenigstein Fires and further alleging that the Thomas and/or Koenigstein Fires proximately caused the Montecito Mudslides. According to Santa Barbara County initial reports, the Montecito Mudslides destroyed an estimated 135 structures, damaged an estimated 324 structures, and resulted in 21 confirmed fatalities, with two additional fatalities presumed but not officially confirmed.
The lawsuits related to the 2017/2018 Wildfire/Mudslide Events naming SCE as a defendant have been filed by three categories of plaintiffs: individual plaintiffs, subrogation plaintiffs and public entity plaintiffs. A number of the lawsuits also name Edison International as a defendant and some of the lawsuits were filed as purported class actions. As of February 11, 2026, in addition to the outstanding claims of approximately 100 individual plaintiffs, there were alleged and potential claims of certain public entity plaintiffs, including CAL OES, outstanding. SCE has settled all fire suppression claims and subrogation plaintiffs' claims related to the 2017/2018 Wildfire/Mudslide Events, except for one indemnification claim.
In January 2019, SCE filed a cross-complaint against certain local public entities alleging that failures by these entities, such as failure to adequately plan for flood hazards and build and maintain adequate debris basins, roads, bridges and other channel crossings, among other things, caused, contributed to or exacerbated the losses that resulted from the Montecito Mudslides. Once SCE has settled all individual plaintiff claims in the TKM litigation that impact the corresponding cross-claims, SCE intends to appeal certain procedural issues to maintain its ability to pursue the cross-claims.

The litigation could take a number of years to be completely resolved because of the complexity of the matters and number of plaintiffs. As of February 11, 2026, SCE has entered into settlements with approximately 13,700 individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events litigation. The statutes of limitations for individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events have expired.
In October 2021, SCE and the SED executed an agreement to resolve the SED's investigations into the 2017/2018 Wildfire/Mudslide Events and three other 2017 wildfires for, among other things, aggregate costs of $550 million. The $550 million in costs was composed of a $110 million fine to be paid to the State of California General Fund, $65 million of shareholder-funded safety measures, and an agreement by SCE to waive its right to seek cost recovery in CPUC-jurisdictional rates for $125 million and $250 million of third-party uninsured claims payments (and related financing costs) in the TKM litigation and the Woolsey Fire litigation, respectively. The SED Agreement provides that SCE may, on a permanent basis, exclude from its ratemaking capital structure any after-tax charges to equity or debt borrowed to finance costs incurred under the SED Agreement. The SED Agreement also imposes other obligations on SCE, including reporting requirements and safety-focused studies. SCE did not admit imprudence, negligence, or liability with respect to the 2017/2018 Wildfire/Mudslide Events in the SED Agreement.
2017 Creek Fire
The "Creek Fire" originated near Sylmar in Los Angeles County in December 2017 and burned approximately 16,000 acres, destroyed an estimated 123 structures, damaged an estimated 81 structures, and resulted in 3 civilian injuries. While the United States Forest Service's ("USFS") January 2018 report of investigation concluded that the Los Angeles Department of Water and Power ("LADWP") long-span transmission lines slapping together in high winds resulted in arcing and ignition of the fire, in August 2024, the USFS issued a supplemental report concluding that the fire was caused by SCE power lines. In 2023, the USFS dismissed its claim against LADWP and filed a claim against SCE to recover over $40 million for fire-suppression costs incurred by the USFS and environmental damage to U.S. lands. Multiple other lawsuits related to the Creek Fire were also filed by individual plaintiffs and subrogation plaintiffs naming SCE as defendant. SCE has settled substantially all of the claims that were filed against it related to the Creek Fire and does not expect to incur additional losses in excess of amounts accrued for the Creek Fire.
103
Table of Contents
2019 Saddle Ridge Fire
The "Saddle Ridge Fire," originated in Los Angeles County in October 2019 and burned approximately 9,000 acres, destroyed an estimated 19 structures, damaged an estimated 88 structures, and resulted in one fatality and injuries to eight  firefighters. In August 2023, SCE received a signed report of investigation from the LAFD, in which the LAFD stated with respect to the Saddle Ridge Fire that the cause of ignition was unintentional, the form of heat was undetermined, the item first ignited was undetermined and the material type first ignited was undetermined. The LAFD report noted that no other competent ignition sources other than SCE's transmission lines were found in the specific origin area of the Saddle Ridge Fire. The SED conducted an investigation with respect to the Saddle Ridge Fire and issued an undated report listing alleged violations of CPUC General Orders by SCE and noting that the alleged violations, under certain circumstances, could have led to a fire ignition. Multiple lawsuits related to the Saddle Ridge Fire were filed by plaintiffs naming SCE as defendant. An inverse condemnation bench trial in the Saddle Ridge Fire litigation has been set for October 2026. SCE has accrued charges for potential losses relating to the Saddle Ridge Fire.
2020 Bobcat Fire
The "Bobcat Fire" was reported in the vicinity of Cogswell Dam in Los Angeles County in September 2020. The USFS has reported that the Bobcat Fire burned approximately 116,000 acres in Los Angeles County, destroyed an estimated 87 homes, one commercial property and 83 minor structures, damaged an estimated 28 homes and 19 minor structures, and resulted in injuries to six firefighters. In addition, fire authorities have estimated suppression costs at approximately $80 million. An investigation into the cause of the Bobcat Fire was led by the USFS. In May 2023, SCE received a report of investigation from the USFS, in which the USFS finds that the Bobcat Fire was caused when an SCE electrical wire made contact with a tree limb. The SED has concluded its investigation of the Bobcat Fire and found no violations of its rules and regulations by SCE related to the Bobcat Fire. Multiple lawsuits related to the Bobcat Fire were filed by plaintiffs, including individual plaintiffs, subrogation plaintiffs and the United States of America, naming SCE as a defendant. SCE has settled substantially all of the claims that were filed against it related to the Bobcat Fire and does not expect to incur additional losses in excess of amounts accrued for the Bobcat Fire.
2020 Silverado Fire
The "Silverado Fire" originated in Orange County in October 2020 and burned over 12,000 acres. The Orange County Fire Authority ("OCFA"). OCFA jointly with CAL FIRE have reported that the Silverado Fire destroyed five structures, damaged nine other structures and resulted in two firefighter injuries. There were also four other structures damaged or destroyed. In addition, methane re-generation pipelines were destroyed and approximately 200 acres of avocado orchards were damaged in the fire. Fire authorities have estimated suppression costs at approximately $20 million. An investigation into the cause of the Silverado Fire was conducted by the OCFA and CAL FIRE. OCFA and CAL FIRE concluded in their October 2020 report of investigation that contact between an SCE conductor and a T-Mobile USA, Inc. ("T-Mobile") line resulted in ignition of the Silverado Fire. In 2024, SCE paid a fine of approximately $2 million imposed by the SED for alleged failure to comply with maintenance requirements with respect to two conductors. Multiple lawsuits related to the Silverado Fire were filed by plaintiffs, including individual plaintiffs, subrogation plaintiffs, CAL FIRE, T-Mobile, County of Orange and Cal OES, naming SCE as a defendant. SCE has settled substantially all of the claims that were filed against it related to the Silverado Fire and does not expect to incur additional losses in excess of the amounts accrued for the Silverado Fire.
2022 Coastal Fire
The "Coastal Fire" originated in Orange County in May 2022 and burned approximately 200 acres. The Orange County Fire Authority ("OCFA") has reported that the Coastal Fire destroyed 20 residential structures and damaged 11 residential structures. Two firefighters also reportedly sustained minor injuries. In addition, fire authorities have estimated suppression costs at approximately $3 million. While SCE's investigation remains ongoing, SCE's information reflects that a SCE circuit in the area experienced an anomaly (a relay) approximately 2 minutes prior to the reported time of the fire. An investigation into the cause of the Coastal Fire was led by the OCFA. The OCFA has retained SCE equipment in connection with its investigation. In September 2024, SCE received a report of investigation from the OCFA, in which the OCFA finds that the Coastal Fire was unintentionally caused by sparks from overhead SCE electrical equipment igniting vegetation under the equipment. The SED is conducting an investigation with respect to the Coastal Fire and issued a notice of violation in 2025. SCE has settled subrogation plaintiff claims and claims brought by the County of Orange related to the Coastal Fire. Individual plaintiffs have also filed complaints against SCE related to the Coastal Fire. As of February 11, 2026, no trials are scheduled in the Coastal Fire litigation. SCE expects to obtain and review additional information and materials in the possession of third parties during the course of its internal reviews and the litigation process. SCE has accrued charges for potential losses relating to the Coastal Fire.
104
Table of Contents
2022 Fairview Fire
The "Fairview Fire" originated in Riverside County in September 2022 and burned approximately 28,000 acres. CAL FIRE has reported that the Fairview Fire destroyed 22 residential structures, damaged five residential structures, and destroyed or damaged 17 minor structures. CAL FIRE also reported two civilian fatalities, one civilian injury and two injuries to responding fire personnel. In addition, fire authorities have estimated suppression costs at $39 million. While SCE's investigation remains ongoing, SCE's information reflects that an SCE circuit in the area experienced an anomaly (a relay) approximately 8 minutes prior to the reported start time of the fire. In November 2023, SCE received a report of investigation conducted by CAL FIRE, in which CAL FIRE finds that the Fairview Fire was caused when a sagging SCE electrical conductor came in contact with a communication line, causing sparks to fall and ignite surrounding vegetation. In March 2025, the SED issued a citation for approximately $2 million for alleged violations of the SED's rules and regulations, including SCE's failure post-fire to comply with clearance requirements with respect to its electrical conductor. SCE has settled subrogation plaintiff claims related to the Fairview Fire. A jury trial in the Fairview Fire individual plaintiff litigation has been set for June 2026. SCE expects to obtain and review additional information and materials in the possession of third parties during the course of its internal reviews and the litigation process. SCE has accrued charges for potential losses relating to the Fairview Fire.
2025 Eaton Fire
In January 2025, several wind-driven wildfires impacted portions of SCE's service area, causing loss of life, substantial damage to both residential and business properties and service outages for SCE customers. One of the largest of these wildfires, the "Eaton Fire," ignited in SCE's service area in Los Angeles County and spread due to a number of contributing factors under conditions of an extreme Santa Ana windstorm.
CAL FIRE has reported that the Eaton Fire burned approximately 14,000 acres and resulted in 18 civilian fatalities and 9 fire personnel injuries/illnesses. An additional fatality has also been reported to be attributed to the Eaton Fire. In addition, according to preliminary information provided by CAL FIRE, the Eaton Fire destroyed approximately 6,018 single residence structures, 3,146 other minor structures, 96 multiple residences and 158 mixed commercial/residential and nonresidential commercial structures; and damaged approximately 750 residential structures, 260 other minor structures, 28 multiple residences and 35 mixed commercial/residential and nonresidential commercial structures. Fire authorities have estimated suppression costs at approximately $100 million.
The Los Angeles County Fire Department is leading the investigation into the origin and cause of the Eaton Fire, with the assistance of CAL FIRE, and has identified a preliminary area of origin of the fire. SCE has transmission facilities in the preliminary area of origin and the SED is conducting an investigation with respect to the Eaton Fire. Edison International and SCE are also aware of an ongoing investigation by the Los Angeles District Attorney's Office of the Eaton Fire for the purpose of determining whether any criminal violations have occurred. SCE could be subject to material fines, penalties, or restitution if it is determined that it failed to comply with applicable laws and regulations. SCE is not aware of any basis for felony liability with regards to the Eaton Fire.
Multiple lawsuits related to the Eaton Fire have been initiated against SCE. A number of the lawsuits also name Edison International as a defendant and some of the lawsuits were filed as purported class actions. As of February 11, 2026, SCE was aware of approximately 1,500 lawsuits related to the Eaton Fire: representing lawsuits by approximately 20,000 individual plaintiffs and also lawsuits by subrogation plaintiffs and public entity plaintiffs. A bellwether jury trial in the Eaton Fire litigation has been set for January 2027.
SCE's internal review into the facts and circumstances of the Eaton Fire is complex and ongoing. SCE's review includes ongoing inspections of its facilities and records and of third-party information and testing. While SCE has not conclusively determined that its equipment caused the ignition of the Eaton Fire, a viable explanation is that a de-energized idle SCE transmission facility in the preliminary area of origin was associated with the ignition of the fire and SCE is not aware of evidence pointing to another possible source of ignition. Absent additional evidence, SCE believes that it is likely that its equipment could have been associated with the ignition of the Eaton Fire and is pursuing settlement of claims through its Wildfire Recovery Compensation Program.
SCE has entered into settlements with insurance claimants and claimants under its Wildfire Recovery Compensation Program related to the Eaton Fire. As of December 31, 2025, SCE had recorded $1.1 billion in losses related to these settlements. SCE also recorded expected recoveries from customer-funded self-insurance of $917 million, from the Wildfire Fund of $134 million, and through FERC electric rates of $70 million, including $19 million related to settlements paid and $51 million of expected recovery through cost deferral. The net after tax charge to earnings recorded is $9 million, the after-tax impact of the required $12.5 million shareholder contribution related to SCE's customer-funded self-insurance coverage.
105
Table of Contents
No admission of wrongdoing or liability was made in reaching the settlements described above and the claimants party to the settlements have agreed to release SCE and Edison International from all claims and potential claims related to or arising from the Eaton Fire.
In light of pending litigation, it is probable that Edison International and SCE will incur additional material losses in connection with the Eaton Fire. Given, among other things, the complexities associated with estimating damages, the large number and varying types of claims and the interrelationship among the claims, uncertainties related to the sufficiency of insurance held by plaintiffs and potential plaintiffs, and uncertainties related to litigation processes and the Wildfire Recovery Compensation Program, Edison International and SCE are currently unable to reasonably estimate a range of losses that may be incurred in connection with the Eaton Fire.
Settlement of Claims
The following table presents settlements paid.
(in millions)
Inception to December 31, 2025
202520242023
2017/2018 Wildfire/Mudslide Events$9,688 $234 $779 $1,034 
Other Wildfire Events943 379 361 190 
Eaton Fire237 237 — — 
Total $10,868 $850 $1,140 $1,224 
Edison International and SCE have not admitted wrongdoing or liability as part of any settlements related to the 2017/2018 Wildfire/Mudslide Events, the Other Wildfire Events, or the Eaton Fire. SCE continues to explore reasonable settlement opportunities with plaintiffs in outstanding wildfire litigation.
Accrued Losses
The following table presents changes in accrued losses since December 31, 2024:
(in millions)2017/2018 Wildfire/Mudslide EventsOther Wildfire EventsEaton FireTotal
Balance at December 31, 2024$426 $575 $— $1,001 
Increase in accrued losses— 21 1,134 1,155 
Amounts paid(234)(379)(237)(850)
Balance at December 31, 2025$192 $217 $897 $1,306 
Edison International's and SCE's consolidated balance sheets included fixed payments to be made under settlements and accrued estimated losses presented in the tables below:
(in millions)2017/2018 Wildfire/Mudslide EventsOther Wildfire EventsEaton FireTotal
Current portion of wildfire-related claims liabilities1
$31 $4 $550 $585 
Long term wildfire-related claims liabilities2
161 213 347 721 
Total balance at December 31, 2025
$192 $217 $897 $1,306 
(in millions)2017/2018 Wildfire/Mudslide EventsOther Wildfire EventsTotal
Current portion of wildfire-related claims liabilities1
$48 $12 $60 
Long term wildfire-related claims liabilities2
378 563 941 
Total balance at December 31, 2024
$426 $575 $1,001 
1At December 31, 2025, current liabilities related to 2017/2018 Wildfire/Mudslide Events consisted of $6 million of settlements executed and $25 million of short-term payables under the SED Agreement. At December 31, 2024, current liabilities related to
106
Table of Contents
2017/2018 Wildfire/Mudslide Events consisted of $29 million of settlements executed and $19 million of short-term payables under the SED Agreement.
2At December 31, 2025, long-term wildfire-related claims related to 2017/2018 Wildfire/Mudslide Events consisted of $17 million of long-term payables under the SED Agreement and $144 million of estimate of expected losses for remaining alleged and potential claims. At December 31, 2024, long-term wildfire-related claims related to 2017/2018 Wildfire/Mudslide Events consisted of $38 million of long-term payables under the SED Agreement and $340 million of estimate of expected losses for remaining alleged and potential claims.
Management reviews its loss estimates for remaining alleged and potential claims related to wildfire litigation quarterly. Edison International and SCE have accrued their best estimate of expected losses for remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events and at the low end of the estimated range of reasonably possible losses for the Other Wildfire Events as no amount within the range of reasonably possible losses for the Other Wildfire Events appears, at this time, to be a better estimate than any other amount within the range.
Edison International and SCE may incur a material loss in excess of amounts accrued in connection with the remaining alleged and potential claims related to the 2017/2018 Wildfire/Mudslide Events and Other Wildfire Events. Due to the number of uncertainties and possible outcomes related to the 2017/2018 Wildfire/Mudslide Events and Other Wildfire Events litigation, Edison International and SCE cannot estimate the upper end of the range of reasonably possible losses that may be incurred in connection with the 2017/2018 Wildfire/Mudslide Events or the Other Wildfire Events. The estimated losses for the 2017/2018 Wildfire/Mudslide Events do not include estimates of potential losses related to certain potential public entity plaintiff claims, including CAL OES's claim in the TKM litigation, for which the statute of limitations has been tolled, as losses from these alleged and potential claims are not estimable at this time.
While SCE recorded losses related to settlements that have been entered into related to the Eaton Fire, Edison International and SCE are currently unable to reasonably estimate a range of losses that may be incurred in connection with the Eaton Fire.
For the years ended December 31, 2025, 2024, and 2023, SCE recorded wildfire-related claims, net of expected recoveries, as follows:
Year ended December 31, 2025
(in millions)2017/2018 Wildfire/Mudslide EventsOther Wildfire Events
Eaton Fire2
Total
Wildfire-related claims$— $21 $1,134 $1,155 
Expected recoveries from insurance and third parties1
— (82)— (82)
Customer-funded wildfire self-insurance
— — (917)(917)
Expected recoveries from Wildfire Fund — — (134)(134)
Expected (recoveries from)/refund to CPUC customers
(2,944)44 — (2,900)
Expected refund to/(revenue from) FERC customers— 3 (70)(67)
Total pre-tax (gain)/charge(2,944)(14)13 (2,945)
Income tax expense/(benefit)824 4 (4)824 
Total after-tax (gain)/charge$(2,120)$(10)$9 $(2,121)
107
Table of Contents
Year ended December 31, 2024
(in millions)2017/2018 Wildfire/Mudslide EventsOther Wildfire EventsTotal
Wildfire-related claims$490 $253 $743 
Expected recoveries from insurance and third parties1
— (96)(96)
Expected revenue from FERC customers
(27)(9)(36)
Total pre-tax charge463 148 611 
Income tax benefit(130)(42)(172)
Total after-tax charge$333 $106 $439 
Year ended December 31, 2023
(in millions)2017/2018 Wildfire/Mudslide EventsOther Wildfire EventsTotal
Wildfire-related claims$630 $184 $814 
Expected recoveries from insurance and third parties1
— (149)(149)
Expected revenue from FERC customers
(37)(2)(39)
Total pre-tax charge593 33 626 
Income tax benefit(165)(9)(174)
Total after-tax charge$428 $24 $452 
1In 2025, EIS, a wholly-owned subsidiary of Edison International, incurred $50 million insurance expense, which consisted of $47 million of wildfire claims and $3 million of related legal costs. In 2024 and 2023, EIS incurred $4 million and $3 million insurance expenses, respectively. These amounts were included in the insurance recoveries of SCE but were excluded from those of Edison International.
2In 2025, SCE recorded $1,134 million in losses related to settlements, including accrued losses. Of these accrued losses, $51 million was deferred as a FERC regulatory asset, eligible to be included in FERC rates when the losses are paid. As a result, SCE's consolidated statements of income for the year ended December 31, 2025 reported wildfire-related claims of $1,083 million and FERC revenue of $19 million related to the Eaton Fire.
In total, through December 31, 2025, SCE has recorded losses of $12.2 billion, expected recoveries from insurance and third parties of $2.8 billion, expected recoveries through electric rates of $3.5 billion, expected recoveries from customer-funded wildfire self-insurance of $0.9 billion, and expected recoveries from the Wildfire Fund of $0.1 billion related to the 2017/2018 Wildfire/Mudslide Events, the Other Wildfire Events, and the Eaton Fire. The after-tax net charges to earnings recorded through December 31, 2025, have been $3.4 billion.
Recoveries
SCE has exhausted expected insurance recoveries related to the 2017/2018 Wildfire/Mudslide Events. Expected recoveries from insurance recorded for the Other Wildfire Events are supported by SCE's insurance coverage for multiple policy years and for the Eaton Fire by its customer-funded self-insurance coverage and the Wildfire Fund. Edison International and SCE record a receivable for insurance recoveries when recovery of a recorded loss is determined to be probable.
The CPUC and FERC may not allow SCE to recover uninsured losses through electric rates, including by FERC requiring refund of amounts recovered, if it is determined that such losses were not prudently incurred. Under accounting standards for rate-regulated enterprises, SCE defers costs as regulatory assets in the period it concludes that such costs are probable of future recovery in electric rates. SCE utilizes objectively determinable evidence to form its view on the probability of future recovery.
Fines and penalties incurred in connection with a wildfire are not recoverable from insurance, the Wildfire Fund or through electric rates.
While Edison International and SCE may incur material losses in excess of the amounts accrued for certain of the Other Wildfire Events, Edison International and SCE expect that additional losses incurred in connection with any such fire, will be covered by insurance, subject to self-insured retentions and co-insurance, and expect that any such additional losses after expected recoveries from insurance and through electric rates will not be material.
108
Table of Contents
The following table sets forth SCE's total recoveries received since inception and expected to receive as of December 31, 2025:
(in millions)2017/2018 Wildfire/Mudslide EventsOther Wildfire Events
Eaton Fire
Total
Recoveries from insurance and third parties$2,000 $800 $— $2,800 
Customer-funded wildfire self-insurance
— — 917 917 
Wildfire Fund recoveries— — 134 134 
FERC recoveries440 22 70 532 
CPUC- RMBA recoveries— 12 — 12 
CPUC-WEMA deferral2,944 96 — 3,040 
Total$5,384 $930 $1,121 $7,435 
The following tables summarize expected recoveries from insurance and third parties, and through electric rates as of December 31, 2025 and 2024:
December 31, 2025
(in millions)
2017/2018 Wildfire/Mudslide Events
Other Wildfire Events
Eaton Fire
Total
Short-term receivables from customer-funded wildfire self-insurance$— $— $709 $709 
Long-term receivables from insurance and third parties
— 237— 237
Long-term receivables from Wildfire Fund recoveries— — 134 134 
FERC related balancing accounts27 20 70 117 
CPUC-regulatory assets2,944 96 — 3,040 
Total$2,971 $353 $913 $4,237 
December 31, 2024
(in millions)
2017/2018 Wildfire/Mudslide Events
Other Wildfire EventsTotal
Long-term receivables from insurance and third parties$— $434 $434 
FERC related balancing accounts64 9 73 
CPUC-regulatory assets— 140 140 
Total$64 $583 $647 
Recoveries through Insurance
For events that occurred in 2017 and early 2018, principally the Thomas and Koenigstein Fires and Montecito Mudslides, SCE had $1.0 billion of wildfire-specific insurance coverage, subject to a self-insured retention of $10 million per occurrence. For the Woolsey Fire, SCE had an additional $1.0 billion of wildfire-specific insurance coverage, subject to a self-insured retention of $10 million per occurrence. SCE recovered $2.0 billion from its insurance carriers in relation to the claims related to the 2017/2018 Wildfire/Mudslide Events and $18 million related to the Creek Fire. Additional insurance was not available for the Creek Fire because wildfire insurance for the period in which the fire was ignited was almost fully exhausted as a result of the TKM litigation.
SCE has approximately $1.2 billion of wildfire-specific insurance coverage for events that occurred during the period June 1, 2019 through June 30, 2020, subject to up to $165 million of co-insurance and self-insured retention, which resulted in net coverage of approximately $1.0 billion.
109
Table of Contents
SCE has approximately $1.0 billion of wildfire-specific insurance coverage for events that occurred during the period July 1, 2020 through June 30, 2021, subject to up to $130 million of self-insured retention and co-insurance per fire, which results in net coverage of approximately $870 million.
SCE has approximately $1.0 billion of wildfire-specific insurance coverage for events that occurred during the period July 1, 2021 through June 30, 2022, subject to up to $163 million of self-insured retention and co-insurance per fire, which resulted in net coverage of approximately $837 million.
SCE has approximately $1.0 billion of wildfire-specific insurance coverage for events that occurred during the period July 1, 2022 through June 30, 2023, subject to up to $63 million of self-insured retention and co-insurance per fire, which results in net coverage of approximately $937 million.
SCE has $1.0 billion of customer-funded self-insurance coverage available for wildfires ignited between January 1, 2025 and December 31, 2025, including the Eaton Fire, under its self-insurance program described below, subject to up to a maximum possible contribution of $12.5 million. SCE will exhaust self-insurance recoveries available for losses related to the Eaton Fire as a result of costs incurred and settlements entered into as of February 11, 2026.
SCE has $1.0 billion of customer-funded self-insurance coverage available for wildfires ignited between January 1, 2026 and December 31, 2026 under its self-insurance program described below, subject to up to a maximum possible contribution of $12.5 million. SCE's self-insurance program meets its obligation to maintain reasonable insurance coverage under the California Wildfire Legislation for the January 1, 2026 through December 31, 2026 period.
SCE's wildfire insurance expense for the July 1, 2022 through June 30, 2023 policy period was approximately $450 million, of which $357 million was paid to commercial insurance carriers (commercial insurance carriers other than EIS are referred to herein as "Third-Party Commercial Insurers"). The difference between the Third-Party Commercial Insurer cost and total cost for the July 1, 2022 through June 30, 2023 policy period was paid in premiums to EIS (See Note 17 for further information). Wildfire insurance premiums paid for the July 1, 2022 through June 30, 2023 policy period are being recovered through customer rates. As a result of an EIS insurance policy amendment, in the first quarter of 2025, EIS recorded a $50 million wildfire insurance expense (by utilizing the premiums already collected as discussed above), and SCE recorded the corresponding insurance recovery from EIS, which reduced expected WEMA recoveries. On the Edison International consolidated statements of income, the EIS insurance expense is eliminated with SCE's insurance recovery from EIS.
In May 2023, the CPUC allowed SCE to establish an expanded self-insurance program for wildfire-related costs that will be funded through CPUC-jurisdictional rates, in lieu of obtaining wildfire liability insurance from the commercial insurance market. Beginning on July 1, 2023, SCE implemented its customer-funded wildfire self-insurance program. In 2023 and 2024, SCE collected $150 million and $300 million, respectively, through CPUC-jurisdictional rates in support of SCE's customer-funded wildfire self-insurance program.
In July 2024, the CPUC issued a decision in the 2025 GRC proceeding authorizing this self-insurance framework to continue through at least 2028, supporting a self-insurance fund of up to $1.0 billion per policy year. From 2025 through 2028, $300 million will be collected annually until a total available self-insurance accrual amount of $1.0 billion is achieved. SCE collected $300 million in 2025 through CPUC-jurisdictional rates in support of its customer-funded wildfire self-insurance program.
As losses are accrued for wildfire-related claims for wildfires that occur between July 1, 2023 and the end of 2028, customer rates will be increased in subsequent years, as needed, to allow for full recovery of the amounts accrued up to $1.0 billion per policy year, subject to a shareholder contribution of 2.5% of any self-insurance costs ultimately paid exceeding $500 million in any policy year, up to a maximum contribution of $12.5 million per policy year. SCE expects to adjust customer rates in 2026 due to expected recoveries from customer-funded self-insurance in connection with the Eaton Fire.
Recoveries through Electric Rates
CPUC recoveries pre-AB 1054
Regulatory recovery of SCE's losses realized in connection with the 2017/2018 Wildfire/Mudslide Events in excess of available insurance is subject to approval by regulators. Under accounting standards for rate-regulated enterprises, SCE defers costs as regulatory assets in the period it concludes that such costs are probable of future recovery in electric rates. SCE utilizes objectively determinable evidence to form its view on probability of future recovery. The only precedent in which a California investor-owned utility sought recovery for uninsured wildfire claims related costs and the CPUC made a prudency determination is SDG&E's requests for cost recovery related to 2007 wildfire activity, where the FERC allowed recovery of all FERC-jurisdictional wildfire claims related costs while the CPUC rejected recovery of all CPUC-jurisdictional wildfire claims related costs based on a determination that SDG&E did not meet the CPUC's prudency
110
Table of Contents
standard ("SDG&E Decision"). The SDG&E Decision is evidence of a California investor-owned utility seeking recovery for uninsured wildfire-related costs and FERC allowing recovery of all FERC-jurisdictional wildfire-related costs while the CPUC rejected recovery of all CPUC-jurisdictional wildfire-related costs based on a determination that the utility did not meet the CPUC's prudency standard.
In August 2023, SCE filed an application to seek CPUC-jurisdictional rate recovery of prudently incurred losses related to the Thomas Fire, the Koenigstein Fire and the Montecito Mudslides, consisting of uninsured claims and associated costs, including legal costs and financing costs. In January 2025, the CPUC approved the TKM Settlement Agreement and closed the proceeding. Under the TKM Settlement Agreement, SCE is authorized to recover 60%, or approximately $1.6 billion, of approximately $2.7 billion of losses, consisting of approximately $1.3 billion of uninsured claims paid as of May 31, 2024 and $0.3 billion of associated costs, composed of legal fees and financing costs incurred as of May 31, 2024 and estimated ongoing financing costs. SCE is also authorized to recover 60% of claims paid and related costs incurred after May 31, 2024, other than for $125 million of uninsured claims and related financing costs which SCE waived its right to seek recovery of under the SED Agreement. As a result, in the first quarter of 2025, SCE recorded a regulatory asset for recoveries authorized under the TKM Settlement Agreement. SCE was also authorized to recover approximately $55 million of approximately $65 million in incremental restoration costs, inclusive of operations and maintenance expenses, incurred related to the Thomas and Koenigstein Fires. Additionally, SCE recorded $50 million of shareholder-funded wildfire mitigation expenses.
In October 2024, SCE filed an application (the "Woolsey Application") to seek CPUC-jurisdictional rate recovery of prudently incurred losses related to the Woolsey Fire, consisting of uninsured claims and associated costs, including legal and financing costs. In December 2025, the CPUC approved the Woolsey Settlement Agreement and closed the proceeding. Under the Woolsey Settlement Agreement, SCE is authorized to recover 35%, or approximately $2.0 billion, of approximately $5.6 billion of losses, consisting of approximately $1.6 billion of uninsured claims paid as of May 31, 2025, and $0.4 billion of costs, comprised of legal costs paid as of May 31, 2025, and estimated ongoing financing costs. SCE is also authorized to recover 35% of losses paid after May 31, 2025. SCE’s requests for recovery exclude $250 million of uninsured claims and related financing costs which SCE waived its right to seek recovery of under the SED Agreement. As a result, in the fourth quarter of 2025, SCE recorded a regulatory asset for recoveries authorized under the Woolsey Settlement Agreement. SCE was also authorized to recover approximately $71 million of approximately $84 million in incremental restoration costs, inclusive of operations and maintenance expenses, incurred related to the Woolsey Fire.
In the Woolsey Settlement Agreement, SCE also waived its right to seek recovery of uninsured losses tracked in a Wildfire Expense Memorandum Account and incurred in connection with fires that ignited prior to July 12, 2019, the date AB 1054 was adopted, including the Creek Fire. SCE estimates that the waived pre-AB 1054 losses are approximately $157 million.
CPUC recoveries post-AB 1054
Under accounting standards for rate-regulated enterprises, SCE defers costs as regulatory assets in the period it concludes that such costs are probable of future recovery in electric rates. SCE utilizes objectively determinable evidence to form its view on probability of future recovery.
The SDG&E Decision was prior to the adoption of AB 1054 on July 12, 2019, after which date AB 1054 clarified that the CPUC must find a utility to be prudent if the utility's conduct related to the ignition was consistent with actions that a reasonable utility would have undertaken in good faith under similar circumstances, at the relevant point in time, and based on the information available at that time. Further, utilities with a valid safety certification at the time of the relevant wildfire will be presumed to have acted prudently related to a wildfire ignition unless a party in the cost recovery proceeding creates serious doubt as to the reasonableness of the utility's conduct, at which time, the burden shifts back to the utility to prove its conduct was prudent.
The Eaton Fire and each of the Other Wildfire Events discussed above, with the exception of the Creek Fire, was ignited after July 12, 2019, and SCE has held a valid safety certification since July 15, 2019. While a California investor-owned utility has not yet sought a prudency review related to recovery for uninsured claims and other costs related to wildfires ignited after the adoption of AB 1054, SCE believes that for fires ignited after July 12, 2019, and for investor-owned utilities holding a safety certification at the time of the fire, the CPUC will apply a standard of review similar to that applied by the FERC which presumes all costs requested by an investor-owned utility are reasonable and prudent unless serious doubt as to the reasonableness of the utility's conduct is created. As such, SCE has concluded, at this time, that uninsured CPUC-jurisdictional wildfire-related costs related to wildfire events occurring after AB 1054 that it has deferred as regulatory assets are probable of recovery through electric rates. SCE will continue to evaluate the probability of recovery based on available evidence, including regulatory decisions, such as any CPUC decisions illustrating the interpretation and/or application of the prudency standard under AB 1054, and, for each applicable fire, evidence that could create serious doubt as to the reasonableness of SCE's conduct relative to that fire. The CPUC may not allow SCE to
111
Table of Contents
recover uninsured losses related to the wildfire events through electric rates if it is determined that such losses were not prudently incurred.
FERC recoveries
Through the operation of its FERC Formula Rate, and based upon the precedent established in SDG&E's recovery of FERC-jurisdictional wildfire-related costs, SCE believes it is probable it will recover its FERC-jurisdictional costs related to the 2017/2018 Wildfire/Mudslide Events, the Other Wildfire Events, and the Eaton Fire. FERC recoveries are subject to refund, and SCE will continue to evaluate the probability of recovery of FERC-jurisdictional costs related to the 2017/2018 Wildfire/Mudslide Events, the Other Wildfire Events, and the Eaton Fire based on available evidence, including any FERC decisions to allow or disallow recovery of FERC-jurisdictional wildfire related costs based on a state regulator's decision on whether to permit recovery of related costs.
Recoveries through the Wildfire Fund
SCE has advised the administrator of the Wildfire Fund that it anticipates seeking reimbursement of eligible claims arising from the Eaton Fire from the Initial Account and the administrator has confirmed that the Eaton Fire is a "covered wildfire" for purposes of accessing the Initial Account. SCE will be reimbursed for losses incurred in excess of $1.0 billion for eligible claims for third-party damages related to the Eaton Fire from the Initial Account, subject to approval of the fund administrator and the Initial Account's claims-paying capacity. The fund administrator has reported that, as of September 30, 2025, the fund's claim paying capacity for the Eaton Fire exceeds $21 billion. Edison International and SCE record a receivable for recoveries from the Wildfire Fund when recovery of a recorded loss from the fund is determined to be probable.
SCE will file an application with the CPUC for review of its costs and expenses related to the Eaton Fire after it has resolved all or, if authorized by the CPUC, substantially all third-party damage claims related to the fire, or upon earlier request of the fund administrator. The CPUC will determine the prudency of SCE's ignition-related conduct in a formal proceeding. If the CPUC finds that SCE's conduct related to the ignition of the Eaton Fire was not prudent, SCE will be required to reimburse the Initial Account only for amounts disallowed by the CPUC up to the applicable Liability Cap of approximately $4.3 billion, unless the fund administrator finds that SCE's actions or inactions relative to the ignition of the Eaton Fire constitute conscious or willful disregard of the rights and safety of others, in which case SCE will be required to reimburse the Initial Account for withdrawn amounts that the CPUC disallowed.
SCE will be able to seek recovery of prudently incurred uninsured wildfire costs not covered by the Initial Account, assessed under the prudency standard clarified under AB 1054, through electric rates.
Environmental Remediation
SCE records its environmental remediation liabilities when site assessments and/or remedial actions are probable and a range of reasonably likely cleanup costs can be estimated. SCE reviews its sites and measures the liability quarterly, by assessing a range of reasonably likely costs for each identified site using currently available information, including existing technology, presently enacted laws and regulations, experience gained at similar sites, and the probable level of involvement and financial condition of other potentially responsible parties. These estimates include costs for site investigations, remediation, operation and maintenance, monitoring and site closure. Unless there is a single probable amount, SCE records the low end of this reasonably likely range of costs (reflected in "Other long-term liabilities") at undiscounted amounts as timing of cash flows is uncertain.
At December 31, 2025, SCE's recorded estimated minimum liability to remediate its 18 identified material sites (sites with a liability balance as of December 31, 2025, in which the upper end of the range of the costs is at least $1 million) was $218 million, including $148 million related to San Onofre. In addition to these sites, SCE also has 16 immaterial sites with a liability balance on December 31, 2025 for which the total minimum recorded liability was $4 million. Of the $222 million total environmental remediation liability for SCE, $213 million has been recorded as a regulatory asset. SCE expects to recover $32 million through an incentive mechanism that allows SCE to recover 90% of its environmental remediation costs at certain sites (SCE may request to include additional sites in this mechanism), and $181 million through proceedings that allow SCE to recover up to 100% of the costs incurred at certain sites through customer rates. SCE's identified sites include several sites for which there is a lack of currently available information, including the nature and magnitude of contamination, and the extent, if any, that SCE may be held responsible for contributing to any costs incurred for remediating these sites. Thus, no reasonable estimate of cleanup costs can be made for these sites.
The ultimate costs to clean up SCE's identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process, such as: the extent and nature of contamination; the scarcity of reliable data for identified sites; the varying costs of alternative cleanup methods; developments resulting from investigatory studies; the possibility of identifying additional sites; and the time periods over which site remediation is expected to occur. SCE believes that, due to these uncertainties, it is reasonably possible that cleanup costs at the identified material sites and
112
Table of Contents
immaterial sites could exceed its recorded liability by up to $87 million and $2 million, respectively. The upper limit of this range of costs was estimated using assumptions least favorable to SCE among a range of reasonably possible outcomes.
SCE expects to clean up and mitigate its identified sites over a period of up to approximately 35 years, though some sites may require a longer time period. Remediation costs for each of the next 5 years are expected to range from $1 million to $20 million. Costs incurred for years ended December 31, 2025, 2024 and 2023 were $15 million, $17 million and $11 million, respectively, and were included in the "Operation and maintenance" expense on the consolidated statements of income.
Based upon the CPUC's regulatory treatment of environmental remediation costs incurred at SCE, SCE believes that costs ultimately recorded will not materially affect its results of operations, financial position or cash flows. There can be no assurance, however, that future developments, including additional information about existing sites or the identification of new sites, will not require material revisions to estimates.
Nuclear Insurance
Federal law limits public offsite liability claims for bodily injury and property damage from a nuclear incident to the amount of available financial protection, which is currently approximately $560 million for San Onofre and $16.3 billion for Palo Verde. As of January 1, 2025, SCE and other owners of San Onofre and Palo Verde have purchased the maximum private primary insurance available ($500 million) through a Facility Form issued by American Nuclear Insurers ("ANI"). In the case of San Onofre, the balance is covered by a US Government indemnity. In the case of Palo Verde, the balance is covered by a loss sharing program among nuclear reactor licensees. If a nuclear incident at any licensed reactor in the United States, which is participating in the loss sharing program, results in claims and/or costs which exceed the primary insurance at that plant site, all participating nuclear reactor licensees could be required to contribute their share of the liability in the form of a deferred premium.
The ANI Facility Form coverage includes broad liability protection for bodily injury or offsite property damage caused by the nuclear energy hazard at San Onofre or Palo Verde, or while radioactive material is in transit to or from San Onofre or Palo Verde. The Facility Form, however, includes several exclusions. First, it excludes onsite property damage to the nuclear facility itself and onsite cleanup costs, but as discussed below SCE maintains separate Nuclear Electric Insurance Limited ("NEIL") property damage coverage for such events. Second, tort claims of onsite workers are excluded, but SCE also maintains an ANI Master Worker Form policy that can provide coverage for non-licensee workers. This program provides a shared industry aggregate limit of $500 million. Industry losses covered by this program could reduce limits available to SCE. Third, offsite environmental costs arising out of government orders or directives, including those issued under the Comprehensive Environmental Response, Compensation and Liability Act, also known as CERCLA, are excluded, with exceptions from clearly identifiable accidents.
SCE withdrew from participation in the secondary insurance pool for San Onofre for offsite liability insurance effective January 5, 2018. Based on its ownership interests in Palo Verde, SCE could be required to pay a maximum of approximately $79 million per nuclear incident for future incidents. However, it would have to pay no more than approximately $12 million per future incident in any one year. Based on its ownership interests in San Onofre and Palo Verde prior to January 5, 2018, SCE could be required to pay a maximum of approximately $255 million per nuclear incident and a maximum of $38 million per year per incident for liabilities arising from events prior to January 5, 2018, although SCE is not aware of any such events. If the public liability limit above is insufficient, federal law contemplates that additional funds may be appropriated by Congress. This could include an additional assessment on all licensed reactor operators as a measure for raising further federal revenue.
SCE is a member of NEIL, a mutual insurance company owned by entities with nuclear facilities. NEIL provides insurance for nuclear property damage, including damages caused by acts of terrorism up to specified limits, and for accidental outages for active facilities. The amount of nuclear property damage insurance purchased for San Onofre and Palo Verde exceeds the minimum federal requirement of $50 million and $1.1 billion, respectively. These policies include coverage for decontamination liability. Additional outage insurance covers part of replacement power expenses during an accident-related nuclear unit outage. The accidental outage insurance at San Onofre has been canceled as a result of the permanent retirement, but that insurance continues to be in effect at Palo Verde.
If NEIL losses at any nuclear facility covered by the arrangement were to exceed the accumulated funds for these insurance programs, SCE could be assessed retrospective premium adjustments of up to approximately $17 million per year. Insurance premiums are charged to operating expense.
113
Table of Contents
Note 13. Leases
Leases as Lessee
SCE enters into various agreements to purchase power, electric capacity and other energy products that may be accounted for as leases when SCE has dispatch rights that determine when and how a plant runs. SCE also leases property and equipment primarily related to vehicles, office space and other equipment. The terms of the lease contracts included in the table below are primarily 15 to 20 years for PPA leases, 3 to 72 years for office leases, and 5 to 13 years for the remaining other operating leases. Finance leases are immaterial to the periods presented.
The following table summarizes SCE's future lease payments for operating leases as of December 31, 2025:
(in millions)PPA Operating Leases
Other Operating Leases1
2026$94 $72 
202788 67 
202887 61 
202989 54 
203089 43 
Thereafter629 98 
Total lease payments1,076 395 
Amount representing interest237 79 
Lease liabilities$839 $316 
1Excludes escalation clauses based on consumer price or other indices and residual value guarantees that are not considered probable at the commencement date of the lease.
The timing of SCE's recognition of the lease expense conforms to ratemaking treatment for SCE's recovery of the cost of electricity and is included in purchased power for PPA operating leases. The following table summarizes the components of SCE's lease expense:
Years ended December 31,
(in millions)202520242023
PPA leases:
Operating lease cost$108 $115 $503 
Variable lease cost1
1,702 1,700 2,277 
Total PPA lease cost1,810 1,815 2,780 
Other operating leases cost75 64 56 
Total lease cost$1,885 $1,879 $2,836 
1Includes lease costs from legacy renewable energy contracts where payments are based on contingent external factors such as wind, hydro and solar power generation.
114
Table of Contents
Other information related to leases was as follows:
Years ended December 31,
(in millions, except lease term and discount rate)202520242023
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from:
PPA operating leases$108 $115 $503 
Other operating leases72 62 55 
ROU assets obtained in exchange for lease obligations:
PPA operating leases$30 $11 $226 
Other operating leases83 79 69 
Weighted average remaining lease term (in years):
PPA operating leases11.6512.5013.37
Other operating leases8.318.869.56
Weighted average discount rate:
PPA operating leases4.34%4.30%4.30%
Other operating leases4.77%4.50%4.22%
Leases as Lessor
SCE also enters into operating leases to rent certain land and facilities as a lessor. These leases primarily have terms that range from 15 to 65 years. During the years ended December 31, 2025, 2024 and 2023, SCE recognized lease income of $17 million, $18 million, and $17 million, respectively, which is included in operating revenue on the consolidated statements of income. At December 31, 2025, the undiscounted cash flow expected to be received from lease payments for the remaining years is $155 million.
Note 14. Equity
Common Stock
Stock Repurchase Programs
The Edison International Board of Directors authorizes stock repurchase programs to repurchase common stock. These programs are intended to offset dilution from common stock issued under Edison International's long-term incentive compensation programs and are funded using Edison International's working capital. The timing and the amount of any repurchased common stock will be determined by Edison International's management based on their evaluation of market conditions and other factors. Repurchases may be executed through various methods, including open market purchases, privately negotiated transactions, and other transactions in accordance with applicable securities laws. Any repurchased shares of common stock will be retired. The programs do not obligate Edison International to acquire any particular amount of common stock, and may be suspended or discontinued at any time at its discretion.
In December 2025, the Edison International Board of Directors authorized a program that provides for the repurchase of up to $70 million of common stock from February 20, 2026 to March 2, 2027.
In July 2024, the Edison International Board of Directors authorized a program for repurchase of up to $200 million of its common stock until December 2025 (the "2024 Share Repurchase Program"). By December 2024, no authorized repurchase amount remained under the 2024 Share Repurchase Program. In December 2024, the Edison International Board of Directors authorized a program for repurchase of up to $75 million of its common stock from February 2025 until February 2026 (the "2025 Share Repurchase Program").
During the years ended December 31, 2025 and 2024, Edison International repurchased and retired 550,999 and 2,412,203 shares, respectively. As of December 31, 2025, $43 million of common stock remained for repurchase under the 2025 Share Repurchase Program.
115
Table of Contents
Preferred Stock
As of December 31, 2025, Edison International had 414,342 shares of 5.375% Fixed-Rate Reset Cumulative Perpetual Preferred Stock, Series A ("Series A Preferred Stock") and 87,937 shares of 5.00% Fixed-Rate Reset Cumulative Perpetual Preferred Stock, Series B ("Series B Preferred Stock") outstanding, each with a liquidation value of $1,000 per share. The dividends are payable on a semi-annual basis. Beginning March 15, 2026, the dividend rate for Series A Preferred Stock will reset every five years to equal the then-current five-year U.S. Treasury rate plus a spread of 4.698%. For Series B Preferred Stock, the dividend rate will reset on varying dates to equal the then-current five-year U.S. Treasury rate plus a spread that is determined at each reset. The spread for the first reset period starting March 15, 2027 is 3.901%.
In December 2025, Edison International, through a tender offer, repurchased 744,975 shares of Series A Preferred Stock and 415,517 shares of Series B Preferred Stock for $1.2 billion and recognized a loss of $12 million. In 2024, Edison International repurchased 29,000 shares of Series B Preferred Stock via open market repurchases for $28 million and recognized a gain of $1 million. In 2023, Edison International repurchased 90,683 shares of Series A Preferred Stock and 217,546 shares of Series B Preferred Stock via open market repurchases for $289 million and recognized a gain of $16 million. The gains and losses from the repurchases were reflected in "Preferred stock dividend requirements of Edison International" on the consolidated statements of income.
Edison International may, at its option, redeem its preferred stocks in whole or in part during certain periods of time prior to each of the dividend reset dates at a price equal to $1,000 per share plus any accumulated and unpaid dividends. Edison International may also, at its option, redeem the preferred stocks in whole but not in part at a price equal to $1,020 per share plus any accumulated and unpaid dividends within a certain period of time following any change in the criteria rating agencies use that would have adverse effects on the equity credit attributed by rating agencies to the preferred stocks.
The preferred stocks rank senior to Edison International's common stock with respect to dividends rights and distribution rights upon liquidation. The preferred stocks are not subject to any mandatory sinking fund, retirement fund, purchase fund or other similar provisions. Holders of the shares of the preferred stocks do not have the right to require Edison International to repurchase or redeem shares of the preferred stocks.
Redemption of Outstanding Preferred Stock Subsequent to December 31, 2025
On February 10, 2026, Edison International announced the redemption of all outstanding shares of Edison International’s Series A Preferred Stock. The redemption date will be March 9, 2026, and in accordance with the terms of the Series A Preferred Stock, the shares are expected to be redeemed at a price equal to $1,000 per share, plus accumulated and unpaid dividends, if any, to, but excluding, the redemption date.
Preferred and Preference Stock of SCE
SCE's authorized shares are: $100 cumulative preferred – 12 million shares, $25 cumulative preferred – 24 million shares and preference with no par value – 50 million shares. There were no preferred shares issued or outstanding as of December 31, 2025 and 2024.
Shares of SCE's preference stock rank senior to SCE's common stock with respect to dividend rights and distribution rights upon liquidation. SCE's outstanding preference shares are not subject to mandatory redemption and there is no sinking fund requirement for redemptions or repurchases of preference shares. There are no dividends in arrears for the preference shares.
116
Table of Contents
The following table summarizes preference stocks (dividends declared per share are for 2025):
Issue DateShares
Outstanding		Redemption
Price per
Share		Dividends
Declared per
Share		December 31,
(in millions, except shares and per share amounts)20252024
No par value (cumulative):
5.10% Series G
201388,004$2,500 $127.500 $220 $220 
3-month SOFR + 3.132% Series J
2015—2,500 147.744 — 325 
5.45% Series K
201647,4952,500 136.250 119 300 
5.00% Series L
2017190,0042,500 125.000 475 475 
7.50% Series M
2023220,0042,500 187.500 550 550 
6.95% Series N
2024140,0042,500 173.750 350 350 
SCE's preference stock1,714 2,220 
Less: issuance costs(34)(45)
Edison International's preference stock of SCE$1,680 $2,175 
Shares of Series G, K, L, M, and N preference stock may be redeemed by SCE at par, in whole or in part on or after March 15, 2018, March 15, 2026, June 26, 2022, November 22, 2028, and May 13, 2029, respectively. The Series G, K, L, M and N shares may be redeemed at par, in whole, but not in part, at any time prior to March 15, 2018, March 15, 2026, June 26, 2022, November 22, 2028, and May 13, 2029, respectively, if certain changes in tax or investment company law or interpretation (or applicable rating agency equity credit criteria for Series L, M and N only) occur and certain other conditions are satisfied. In December 2025, all of the outstanding Series J preference stock was redeemed. Series K preference stock, distributions will accrue and be payable at a floating rate from and including March 15, 2026. In December 2025, SCE, through a tender offer, repurchased 72,509 shares of its Series K preference stock for $181 million. SCE recorded a $9 million loss on the redemption and repurchase of the preference stocks. The loss was reflected in "Preference stock dividend requirements" on the consolidated statements of income. On February 10, 2026, SCE announced that it will redeem all the remaining shares of its Series K preference stock, which will cause SCE Trust V to redeem all of its outstanding 5.45% Series K trust securities. The redemption date will be March 15, 2026 at the redemption price of $25 per Series K trust security.
Shares of Series G, K, L, M and N preference stock were issued to SCE Trust II, SCE Trust V, SCE Trust VI, SCE Trust VII and SCE Trust VIII, respectively, special purpose entities formed to issue trust securities to the public. The trust securities do not have a maturity date and upon redemption of any shares of the series of preference stock, a corresponding dollar amount of the trust securities will be redeemed by the applicable trust. The applicable trust will make distributions at the same rate and on the same dates on the applicable series of trust securities, if and when the SCE's Board of Directors declares and makes dividend payments on the related preference stock.
117
Table of Contents
Note 15. Other Income, Net
Other income net of expenses is as follows:
Years ended December 31,
(in millions)202520242023
SCE other income (expense):
Equity AFUDC$189 $187 $157 
Increase in cash surrender value of life insurance policies and life insurance benefits46 42 37 
Interest income184 250 261 
Net periodic benefit income – non-service components89 91 100 
Civic, political and related activities and donations(51)(63)(42)
Other(10)(14)(16)
Total SCE other income, net447 493 497 
Other income (expense) of Edison International Parent and Other:
Net losses on equity securities(12)— (3)
Interest income and other3 9 6 
Total Edison International other income, net$438 $502 $500 
Note 16. Supplemental Cash Flows Information
Supplemental cash flows information is:
Edison InternationalSCE
Years ended December 31,
(in millions)202520242023202520242023
Cash payments (receipts)1:
Interest, net of amounts capitalized$1,716 $1,588 $1,401 $1,399 $1,306 $1,155 
Non-cash financing and investing activities:
Dividends declared but not paid:
Common stock338 318 299 430 430 360 
Preference stock of SCE— — 9 — — 9 
Details of debt exchange:
Pollution-control bonds redeemed (2.625%)
— — (135)— — (135)
Pollution-control bonds remarketed (4.50%)
— — 135 — — 135 
1Cash payments (receipts) related to income taxes are disclosed in Note 8.
SCE's accrued capital expenditures for the years ended December 31, 2025, 2024, and 2023 were $918 million, $644 million, and $680 million, respectively. Accrued capital expenditures are included in investing activities in the consolidated statements of cash flows in the period paid.
Note 17. Related-Party Transactions
Edison International and SCE provide and receive various services to and from its subsidiaries and affiliates. Services provided to Edison International by SCE are priced at fully loaded cost (i.e., direct cost of goods or service and allocation of overhead cost). Specified administrative services performed by Edison International or SCE employees, such as payroll and employee benefit programs, are shared among all affiliates of Edison International. Costs are allocated based on one of the following formulas: percentage of time worked, equity in investment and advances, number of employees, or multi-factor (operating revenue, operating expenses, total assets and number of employees). Edison International allocates various corporate administrative and general costs to SCE and other subsidiaries using established allocation factors.
118
Table of Contents
For the years ended December 31, 2025 and 2024, SCE did not purchase wildfire liability insurance from EIS. Beginning on July 1, 2023, in lieu of obtaining wildfire liability insurance from the commercial insurance market, SCE implemented its customer-funded wildfire self-insurance program. In addition, one of the EIS wildfire liability insurance policies was amended in February 2025 to reimburse SCE for $50 million in claim costs and related legal expenses for a wildfire occurring during the July 1, 2022 through June 30, 2023 policy period. For further information, see Note 12. For the year ended December 31, 2022, SCE purchased wildfire liability insurance for premiums of $273 million from EIS. EIS fully reinsured the exposure for these policies through the commercial reinsurance market, with reinsurance limits and premiums equal to those of the insurance purchased by SCE, except for a contract for a premium of $93 million for the 12 months ended June 30, 2023 under which EIS provided insurance protection to SCE. SCE recorded the premium as insurance expense and recorded an equal amount of revenue due to customer funding through regulatory cost recovery mechanisms, therefore there was no earnings impact on SCE's consolidated statements of income. EIS recorded the premium as insurance revenue. On the Edison International consolidated statements of income, the EIS insurance revenue was eliminated with SCE's insurance expense, therefore the SCE customer revenues increased the earnings of Edison International. The amount of insurance expense and corresponding revenue was $44 million for the year ended December 31, 2023. The expected insurance recoveries from previously purchased wildfire-related insurance from EIS included in SCE's consolidated balance sheets were $226 million and $303 million at December 31, 2025 and December 31, 2024, respectively. The expense for wildfire-related insurance premiums paid to EIS was $132 million for the year ended December 31, 2023.
Edison International Foundation ("EIXF") is an unconsolidated not-for-profit organization formed under Section 501(c)(3) of the Internal Revenue Code. All members of EIXF's Board of Directors are officers of Edison International or SCE. Edison International does not have title to, and cannot receive contributions back from, EIXF. Edison International made an irrevocable contribution to EIXF of $19 million for the year ended December 31, 2024, which was reflected in "Other income, net" on Edison International's consolidated statements of income. No contributions were made for the years ended December 31, 2025 and 2023.
Powering Progress is an unconsolidated not-for-profit organization formed under Section 501(c)(4) of the Internal Revenue Code. All members of Powering Progress' Board of Directors are officers of Edison International or SCE. Edison International made an irrevocable contribution to Powering Progress of $10 million for the year ended December 31, 2025, which was reflected in "Other income, net" on Edison International's consolidated statements of income. No contributions were made for the years ended December 31, 2024 and 2023.
119
Table of Contents
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.
CONTROLS AND PROCEDURES (Part II, Item 9A)
Disclosure Controls and Procedures
Based on an evaluation of Edison International's and SCE's disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), as of December 31, 2025, Edison International's and SCE's respective principal executive officers and principal financial officers have concluded that such controls and procedures are effective to ensure that information required to be disclosed by Edison International and SCE in reports that the companies file or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC rules and forms. In addition, Edison International's and SCE's respective principal executive officers and principal financial officers have concluded that such controls and procedures were effective in ensuring that information required to be disclosed by Edison International and SCE in the reports that Edison International and SCE file or submit under the Exchange Act is accumulated and communicated to Edison International's and SCE's management, including Edison International's and SCE's respective principal executive officers and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.
Management's Report on Internal Control Over Financial Reporting
Edison International's and SCE's respective management are responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f), for Edison International and its subsidiaries and SCE, respectively. Under the supervision and with the participation of their respective principal executive officer and principal financial officer, Edison International's and SCE's management conducted an evaluation of the effectiveness of their respective internal controls over financial reporting based on the framework set forth in Internal Control—Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on their evaluations under the COSO framework, Edison International's and SCE's respective management concluded that Edison International's and SCE's respective internal controls over financial reporting were effective as of December 31, 2025. Edison International's internal control over financial reporting as of December 31, 2025 has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report included in this filing, which is incorporated herein by this reference. This annual report does not include an attestation report of SCE's independent registered public accounting firm regarding internal control over financial reporting. Management's report for SCE is not subject to attestation by the independent registered public accounting firm.
Changes in Internal Control Over Financial Reporting
There were no changes in Edison International's or SCE's internal control over financial reporting during the fourth quarter of 2025 that have materially affected, or are reasonably likely to materially affect, Edison International's or SCE's internal control over financial reporting.
Jointly Owned Utility Plant
Edison International's and SCE's respective scope of evaluation of internal control over financial reporting includes their Jointly Owned Utility Projects.
120
Table of Contents
BUSINESS
CORPORATE STRUCTURE, INDUSTRY AND OTHER INFORMATION
Edison International was incorporated in 1987 as the parent holding company of SCE, a California public utility incorporated in 1909. Edison International also owns Trio, a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial and institutional customers.
The principal executive office of Edison International is located at 2244 Walnut Grove Avenue, P.O. Box 976, Rosemead, California 91770, and Edison International's telephone number is (626) 302-2222. The principal executive office of SCE is located at 2244 Walnut Grove Avenue, P.O. Box 800, Rosemead, California 91770, and SCE's telephone number is (626) 302-1212.
This is a combined Annual Report on Form 10-K for Edison International and SCE. Edison International and SCE make available at edisoninvestor.com: Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, Proxy Statements and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act, as soon as reasonably practicable after Edison International and SCE electronically file such material with, or furnishes it to, the SEC. Such reports are also available on the SEC's internet website at sec.gov. The information contained on, or connected to, the Edison investor website is not incorporated by reference into this report.
Subsidiaries of Edison International
SCE – Public Utility
SCE is an investor-owned public utility primarily engaged in the business of supplying and delivering electricity through SCE's electrical infrastructure to an approximately 50,000 square-mile area of southern California. SCE serves approximately 5 million customers in its service area. As of December 31, 2025, SCE's total number of customers by class were as follows:
(in thousands)202520242023
Residential4,6724,6184,576
Commercial625611610
Industrial455
Public authorities706969
Agricultural and other181819
Total5,3895,3215,279
CPUC and FERC rates decouple authorized revenue from the volume of electricity sales and the price of energy procured so that SCE has the opportunity to receive revenue equal to amounts authorized by the relevant regulatory agencies. As a result, the volume of electricity sold does not have a direct impact on SCE's financial results. See "SCE—Overview of Ratemaking Process—CPUC" and "—FERC" for further information.
Trio – Energy Service Provider
Trio is a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial and institutional customers. Trio aims to provide energy solutions that address cost, carbon and complex choices for its customers.
Regulation of Edison International as a Holding Company
As a public utility holding company, Edison International is subject to the Public Utility Holding Company Act. The Public Utility Holding Company Act primarily obligates Edison International and its utility subsidiaries to provide access to their books and records to the FERC and the CPUC for ratemaking purposes.
Edison International is not a public utility and its capital structure is not regulated by the CPUC. The 1988 CPUC decision authorizing SCE to reorganize into a holding company structure, however, imposed certain obligations on Edison International and its affiliates. These obligations include a requirement that SCE's dividend policy continue to be established by the SCE Board of Directors as though SCE were a stand-alone utility company, and that the capital requirements of SCE, as deemed to be necessary to meet SCE's electricity service obligations, shall receive first priority from the Boards of Directors of Edison International and SCE. The CPUC has also promulgated Affiliate Transaction Rules, which, among other requirements, prohibit holding companies from (1) being used as a conduit to provide non-public information to a utility's affiliates and (2) causing or abetting a utility's violation of the rules, including providing preferential treatment to its affiliates.
121
Table of Contents
Human Capital
At December 31, 2025, Edison International had an aggregate of 13,725 employees (excluding interns and employees on leaves of absence), of which 13,235 were full-time employees of SCE or its subsidiaries. In addition to employees, SCE's workforce includes a significant number of contract workers who support SCE's operations. Among these contract workers are Safety Tier 1 Contractors. SCE estimates, based on contractors' self-reported hours worked and a 2,080-hour work year, that there were approximately 9,151 full-time equivalent Safety Tier 1 Contractors supporting SCE operations during 2025. All Safety Tier 1 Contractors engaged in decommissioning activities at San Onofre are managed by the DGC. In addition to Safety Tier 1 Contractors, SCE also uses other contract workers to support its transmission and distribution, vegetation management, information technology and customer service activities.
Approximately 4,600 of SCE's employees are represented by the International Brotherhood of Electrical Workers ("IBEW") under collective bargaining agreements that expire December 31, 2027. In addition, in June 2025, approximately 1,100 of SCE's employees agreed to be represented by the Engineers and Scientists of California Local 20, International Federation of Professional and Technical Engineers ("ESC 20"). As of February 11, 2026, negotiations between ESC 20 and SCE for a collective bargaining agreement are pending. A substantial number of SCE's contract workers are also unionized.
Edison International focuses on various human capital measures and objectives in managing its business, including measures and objectives related to safety, diversity, equity and inclusion and workforce continuity.
Safety
Safety is the first of Edison International’s core values. Edison International is committed to fostering and maintaining a safe environment for its employees, contract workers, customers, and the public. Over the past several years, Edison International has intensified its efforts to improve workforce safety, including an increased focus on, and investment in, maturing a culture of safety ownership among its workforce that empowers employees and contract workers to own their safety, support their team members' safety and contribute to a safe work environment.
Edison International takes efforts to eliminate fatalities and serious injuries, and reduce all injuries in our employee and contractor workforce. Edison International also continues to enhance its workforce safety culture. For instance, SCE uses safety culture assessments for both employee and contractors to measure progress toward improving safety culture. Additionally, all full-time employees are provided with regular safety-related training, particularly for those who work in proximity to high-voltage electrical equipment and other high hazard activities.
SCE has implemented a people and systems safety plan for high hazard organizations. This plan is driven by SCE’s Safety Management System (“SMS”) and safety culture improvement efforts. Foundational to the SMS is the safety risk management pillar that identifies and prioritizes risks and mitigations based on several factors, including worker and leader input. Examples of key risk mitigations targeted by the SMS include developing a multi-year training improvement plan and standardizing processes for safer high hazard work methods.
In 2025, SCE increased oversight of its contracted workforce through hiring of additional safety advisors. Similar to prior years, SCE implemented contractor initiatives to provide additional education on safe work practices, enhance risk awareness and better streamline understanding of SCE expectations. As part of SCE’s safety protocols and contractor safety efforts, it forms incident review teams to address all contractor serious injury incidents, and related corrective actions. The respective contractors are then required to perform a cause evaluation to determine causes and learnings for each incident. Incident review outcomes including any work practice changes, rule updates, and new tools are shared and communicated to SCE employees and contractors for their knowledge, awareness, and implementation. Additionally, to strengthen contractor safety performance, SCE engaged an independent consultant to conduct a comprehensive review and recommend enhancements to contractor safety programs.
122
Table of Contents
Edison International also uses various measures to assess safety performance, including, without limitation, fatalities and serious injury rates for employees and contract workers. The following represents data for 2025:
Employee work-related fatalities0
Employee EEI Serious Injuries
3
Employee EEI SIF Rate1
0.02
Employee DART Rate2
1.54
Contractor work-related fatalities3
0
Safety Tier 1 Contractor EEI Serious Injuries3
1
Safety Tier 1 Contractor EEI SIF Rate1,3
0.01
Safety Tier 1 Contractor DART Rate2,3
0.33
1EEI SIF Rate is calculated by multiplying the total number of 2025 EEI SIF incidents (classified by SCE on or before January 16, 2026) by 200,000 and then dividing by the total number of reported hours worked.

2DART Rate is calculated by multiplying the number of 2025 DARTs (reported to SCE on or before January 11, 2026 for Safety Tier 1 Contractors and classified as a DART by SCE on or before January 16, 2026 for employees) by 200,000 and then dividing by the total number of reported hours worked. The 2026 DART Rates may change based on information received by SCE after January 16, 2026, for Safety Tier 1 Contractors and after January 11, 2026 for employees.
3Represents SCE contractor safety data and data provided by the DGC for contractors that undertake a significant scope of decommissioning activities at San Onofre.
Diversity, Equity and Inclusion
Edison International believes that a merit-based work environment comprised of people with diverse skills, experiences and perspectives is an important driver of success. This merit-based inclusive approach supports a workforce that reflects the customers and communities it serves and enables Edison International to continue to earn public trust and drive better business outcomes. At Edison International, on average, employees in the same role regardless of race/ethnicity or gender identification receive equal pay for equal work. Similar to broader society, when looking at gender or race/ethnicity-specific groups across Edison International without regard to role, female employees and Black and Hispanic employees do not receive comparable pay to male and White employees, respectively, due to lower representation of female, Black and Hispanic employees in higher paying jobs. Edison International is committed to broad recruitment and use of merit-based hiring practices to attract and retain top talent.
The table below provides Edison International's employee diversity data1 as of December 31, 2025:
Employees2
Leaders3
Executives4
Females30 %29 %41 %
Racially/ethnically diverse5
65 %57 %39 %
Racially/ethnically or gender diverse5
73 %67 %64 %
1Calculated using the guidelines SCE uses to calculate the diversity data it reports to the United States Equal Employment Opportunity Commission.
2Excludes interns and employees on a leave of absence.
3"Leaders" represents all non-executive manager and supervisor level employees.
4"Executives" represents all officers and all director level employees.
5Excludes employees of Trio's subsidiary Alfa Energy Ltd. Alfa Energy Ltd.’s workforce is based in the United Kingdom and does not track race/ethnicity data due to regulatory restrictions.
To support Edison International's inclusion efforts, Executives and Leaders are offered training and tools to enable all individuals to excel and to promote teams comprised of people with diverse skills, experiences and perspectives. Edison International uses various measures to assess success of its workforce development initiatives, including without limitation, monitoring hiring, promotion and turnover rates.
123
Table of Contents
Workforce Continuity
Edison International is committed to identifying and developing the talents of its workforce and takes a variety of steps to increase employee engagement and provide employees opportunities for growth. Employees are offered training opportunities, including an onboarding program, technical training, required ethics and compliance training and optional trainings to support career development. SCE estimates that over 99% of active SCE employees completed all assigned training required to be completed in 2025 as part of SCE's enterprise-wide training program. Employees may also be required to take additional trainings based on their job function.
Employees receive competitive compensation packages which include a wide selection of health plans, a 401(k) savings plan with a company match, wellness programs and initiatives, tuition reimbursement, competitive vacation/holiday program, professional development, volunteer programs, employee assistance program, and a philanthropy and matching contribution program.
Edison International uses various measures to assess employee engagement and satisfaction, including, without limitation, conducting regular employee engagement surveys and monitoring turnover. Edison International Parent and SCE's combined Turnover Rate was 6.7% and 7.9% in 2025 and 2024, respectively.
Executives engage in succession planning for leadership positions within the organization. Edison International's and SCE's Boards of Directors also engage in succession planning and talent development discussions for senior officers.
Edison International's Sustainability Report is available on its website. The report and any other information contained on, or connected to, this website are not deemed part of, and are not incorporated by reference into, this Annual Report on Form 10-K.
Insurance
Edison International maintains a property and casualty insurance program for itself and its subsidiaries and excess liability insurance covering liabilities to third parties for bodily injury or property damage resulting from operations. These policies are subject to specific retentions, sub-limits and deductibles, which are comparable to those carried by other utility companies of similar size. Catastrophic events, such as hurricanes and storms, that have not impacted Edison International or its subsidiaries directly have had an impact, and can have future impacts, on insurance markets overall.
While SCE maintains insurance relating to cybersecurity events, such insurance is subject to a number of exclusions and may be insufficient to offset any losses, costs or damage experienced.
SCE also has separate insurance programs for nuclear property and liability, workers compensation and wildfires. For further information on nuclear and wildfire insurance, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies."
SCE
Regulation
CPUC
The CPUC has the authority to regulate, among other things, retail rates, utility distribution-level equipment and assets, energy purchases on behalf of retail customers, SCE capital structure, rate of return, issuance of securities, disposition of utility assets and facilities, oversight of nuclear decommissioning funding and costs, and aspects of the transmission system planning, site identification and construction, including safety and environmental mitigation. The CPUC can assess penalties on any public utility that violates or fails to comply with its rules and requirements, of up to $100,000, for each offense, which could be assessed daily for a continuing violation. The CPUC's enforcement policy authorizes the staff of the CPUC to draft proposed Administrative Consent Orders and Administrative Enforcement Orders, both of which can include fines and serve as alternatives to issuance of a citation or formal investigation proceeding, for CPUC consideration and approval.
FERC
The FERC has the authority to regulate wholesale rates as well as other matters, including unbundled transmission service pricing, rate of return, accounting practices, and licensing of hydroelectric projects. The FERC also has jurisdiction over a portion of the retail rates and associated rate design.
124
Table of Contents
CAISO
The CAISO operates a wholesale energy market primarily in California through which competing electricity generators offer their electricity output to market participants, including electricity retailers. SCE has placed its transmission system under the operational control of the CAISO.
Major transmission projects required for reliability, economic and other policy reasons are identified and approved through the CAISO's annual transmission planning process. Depending on the nature of the project identified, it may be assigned to SCE or set for competitive bid.
The CAISO is conducting transmission planning studies to identify transmission needed to meet a 25 million metric ton GHG emissions target by 2035 set by the CPUC for California's electricity sector to support California's target of reducing overall GHG emissions statewide.
NERC
The FERC assigned administrative responsibility to the NERC to establish and enforce reliability standards and critical infrastructure protection standards, which protect the bulk power system against potential disruptions from cyber and physical security breaches. The critical infrastructure protection standards focus on controlling access to critical physical and cybersecurity assets, including supervisory control and data acquisition systems for the electric grid. The reliability standards define the requirements for planning and operating the bulk power system. Compliance with these standards is mandatory. As of the date of this filing, the maximum penalty that may be levied for violating a NERC reliability or critical infrastructure protection standard is approximately $1.6 million per violation, per day.
OEIS
The OEIS, successor to the CPUC's Wildfire Safety Division, is responsible for, among other things, approving and overseeing compliance with WMPs. As part of overseeing WMP compliance, OEIS can issue notices of nonperformance and recommend that the Commission pursue an enforcement action against an electrical corporation for noncompliance with its approved WMP. Other OEIS tasks include conducting safety culture assessments, approving executive compensation structures, and issuing safety certifications.
NRC
The NRC has jurisdiction with respect to the safety of San Onofre and Palo Verde Nuclear Generating Stations. The NRC regulates commercial nuclear power plants through licensing, oversight and inspection, performance assessment, and enforcement of its requirements. In June 2013, SCE decided to permanently retire and decommission San Onofre. The NRC regulates the decommissioning of San Onofre. For further information, see "Liquidity and Capital Resources—SCE—Decommissioning of San Onofre" in the MD&A.
Other Regulatory Agencies
The construction, planning and project site identification of SCE's transmission lines and substation facilities require compliance with various laws and approval of many governmental agencies in addition to the CPUC and FERC. These include various state regulatory agencies depending on the project location; the U.S. Environmental Protection Agency and other environmental, land management and resource agencies such as the Bureau of Land Management, the U.S. Forest Service, the California Department of Fish and Wildlife, the California Coastal Commission, and the State Water Resources Control Board. In addition, to the extent that SCE transmission line projects pass through lands owned or controlled by Native American tribes, consent and approval from the affected tribes and the Bureau of Indian Affairs are also necessary for the project to proceed.
Compliance with Government Regulations
SCE incurs significant costs to comply with government regulations. These costs, which include operation and maintenance expenses and capital expenses, include without limitation: costs incurred to maintain wildfire insurance coverage required by law; comply with environmental regulations, including licensing requirements, regulations governing California's renewable energy standards and regulations governing the decommissioning of San Onofre; land use and construction regulations; privacy and cybersecurity regulations; and Occupational Safety and Health Administration regulations. SCE also incurs operation and maintenance expenses and capital expenses to comply with requirements set forth in various regulatory decisions, including costs incurred to implement its approved capital projects and safety programs such as its WMPs.
Most costs incurred by SCE to comply with government regulations are authorized in its CPUC and FERC general rate cases and, are therefore, recovered through electric rates. To the extent SCE incurs costs to comply with government regulations above those that are authorized, or prior to obtaining authorization for recovery through rates (for instance
125
Table of Contents
certain costs incurred in line with SCE's obligations under its WMPs and tracked in wildfire mitigation-related memorandum accounts), SCE will seek recovery of such costs through electric rates to the extent they are eligible for recovery. There is no assurance that SCE will be allowed to fully recover these costs. For further information on wildfire mitigation and wildfire insurance costs, see "MD&A—Liquidity and Capital Resources—SCE—Regulatory Proceedings—Wildfire Related Regulatory Proceedings."
SCE earns a rate of return on its authorized capital expenditures included in its rate base. Approximately $1.6 billion of spending on wildfire risk mitigation capital expenditures are not included in rate base under the terms of AB 1054. Further, SCE expects that it will be required to exclude $2.9 billion of wildfire risk mitigation capital expenditures approved on or after January 1, 2026 under the terms of SB 254. For further information, see "—Southern California Wildfires— Recovery of Wildfire-Related Costs—California Wildfire Legislation—Excluded Capital Expenditures."
Overview of Ratemaking Process
CPUC
Revenue authorized by the CPUC through GRC proceedings is intended to provide SCE a reasonable opportunity to recover its costs and earn a return on its net investments in generation and distribution assets and general plant (also referred to as "rate base") on a forecast basis. Revenue is authorized through quadrennial GRC proceedings where the CPUC sets an annual revenue requirement for the test year which is made up of the operation and maintenance costs, depreciation, taxes and a return consistent with the authorized cost of capital (discussed below). In the GRC proceedings, the CPUC also generally approves the level of capital spending on a forecast basis. Following the test year, the revenue requirements for the remaining three years will be set by a methodology established in the GRC proceeding, which has generally, among other items, included annual allowances for escalation in operation and maintenance costs and additional changes in capital-related investments.
SCE's 2025 GRC authorized revenue requirements for 2025, 2026, 2027 and 2028 of $9.7 billion, $10.2 billion, $10.7 billion and $11.2 billion, respectively, with adjustments to the post-test years' revenue requirements, allowing the application of an attrition index to operation and maintenance expenses, tied to the Consumer Price Index and capped at five percent each year, along with budget-based wildfire mitigation capital additions and zero escalation for all of SCE's non-wildfire related capital additions in the attrition years. For further discussion of the 2025 GRC, see "MD&A—Results of Operations—Impact of 2025 GRC."
Beginning with the 2029 GRC, SCE will be required to include affordability metrics in GRC applications where the revenue increase is estimated to exceed one percent of currently authorized revenues systemwide. The CPUC has defined affordability as the degree to which a representative household is able to pay for an essential utility service charge, given its socioeconomic status.
By May 15 in the year preceding each GRC application filing date, SCE is required to file a Risk Assessment and Mitigation Phase ("RAMP") application with the CPUC to provide information about SCE's assessment of its key safety risks and its proposed programs and spending for mitigating those risks. SCE plans to file its RAMP application for the 2029 GRC in May 2026. The information developed during the RAMP informs SCE's proposed projects and funding requests in the subsequent phase of the GRC.
The CPUC regulates SCE's cost of capital, including its capital structure and authorized rates of return. SCE's currently authorized capital structure is 43% long-term debt, 5% preferred equity and 52% common equity. SCE’s authorized capital structure is subject to certain exclusions, for example the waiver of certain expenses and debt related to the 2017/2018 Wildfire/Mudslide Events. For further information on the exclusion related to the 2017/2018 Wildfire/Mudslide Events, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends."
SCE's currently authorized cost of capital for 2026 consists of: cost of long-term debt of 4.71%, cost of preferred equity of 6.89%, and ROE of 10.03%. Based on these cost factors and the capital structure discussed above, SCE’s weighted average return on rate base will be 7.59% for 2026. The cost of capital adjustment mechanism set by the CPUC provides for an adjustment to SCE's authorized cost of capital. The cost of capital adjustment mechanism's benchmark beginning January 1, 2026, is the 12-month, October 1, 2024 through September 30, 2025, average Moody's Baa utility bond yield of 5.94%. If the difference between the benchmark and the average of the same index for the 12-month period from October 1, 2025 to September 30, 2026 exceeds 100-basis points, SCE's CPUC-authorized ROE will be adjusted for 2027 by 20% of the amount of the difference (up or down).
CPUC rates decouple authorized revenue from the volume of electricity sales so that SCE receives revenue equal to amounts authorized. Differences between amounts collected and authorized levels are either collected from or refunded to customers, and, therefore, such differences do not impact operating revenue. Accordingly, SCE is neither benefited nor burdened by the volume of retail electricity sales.
126
Table of Contents
Cost-recovery balancing accounts track the difference between actual expenditures associated with the account, revenue authorized for recovery by the CPUC (authorized revenue requirement), and the actual revenues collected within customer rates to cover those specific expenditures. These balancing accounts are used to track and recover, among other things, SCE's decoupled costs of fuel and purchased power, as well as certain operation and maintenance expenses. SCE earns no return on these activities and although differences between forecasted and actual costs do not impact earnings, such differences do impact cash flows and can change rapidly. SCE also has capital-related balancing accounts on which it earns a return, such as the grid hardening balancing account. Costs tracked in balancing accounts are not subject to after-the-fact reasonableness review unless the balancing accounts are one-way balancing accounts or otherwise subject to a cost cap. SCE also has memorandum accounts, which track costs above authorized levels eligible for cost recovery upon a future reasonableness review. To the extent SCE does not have a tracking mechanism, SCE cannot recover expenses that exceed authorized amounts. However, every subsequent GRC allows SCE to reflect its prior actual investment in plant as a part of the forecast for the next test year.
The 2025 GRC final decision authorized capital expenditures of approximately $1 billion during 2025 - 2028 to support 212 miles of the wildfire mitigation targeted undergrounding ("TUG") program, along with the deployment of 1,653 circuit miles of covered conductors in high fire risk areas. The final decision authorized a two-way Grid Hardening Balancing Account to track the difference between actual TUG costs and Rapid Earth Fault Current Limiter costs up to the approved mile limit and the authorized amounts, with spending in excess of 110% of authorized amounts subject to reasonableness review. SCE is also authorized to record incremental costs that exceed the approved scope in the existing Wildfire Mitigation Plan Memorandum Account, with cost recovery subject to reasonableness review.
SCE's cost-recovery mechanism for its fuel and purchased power-related costs is facilitated in three main balancing accounts, the ERRA, the PABA, and the new system generation balancing account ("NSGBA"). For all three accounts, SCE sets rates based on an annual forecast of the costs that it expects to incur during the subsequent year. In addition, the CPUC has established a "trigger" mechanism for the ERRA and the PABA. The trigger mechanism requires SCE to request an expeditious rate change if the sum of the ERRA balance and the bundled service customers' pro-rata share of the PABA balance exceeds 4% of SCE's prior year generation rate revenue and SCE does not expect the aggregate overcollection or undercollection to fall below 5% of SCE's prior year generation rate revenue within 120 days. For 2026, SCE estimates the 4% and 5% trigger amounts to be approximately $183 million and $229 million, respectively.
For 2025, the 4% and 5% trigger amounts were approximately $234 million and $292 million, respectively. As of December 31, 2025, the ERRA was overcollected by approximately $829 million, the PABA was undercollected by approximately $1.4 billion, and the NSGBA was overcollected by approximately $23 million. In December 2025, the CPUC approved SCE incorporating these year-end balances into customer rates in January 2026.
The majority of fuel and purchased power procurement-related costs eligible for recovery through cost-recovery rates are pre-approved by the CPUC through specific decisions and a procurement plan with predefined standards that establish the eligibility for cost-recovery. If such costs are subsequently found to be non-compliant with this procurement plan, then this could negatively impact SCE's earnings and cash flows. In addition, the CPUC retrospectively reviews outages associated with utility-owned generation and SCE's power procurement contract administration activities through the annual ERRA review proceeding. A CPUC finding that SCE was unreasonable or imprudent with respect to its utility-owned generation outages and contract administration activities, could negatively impact SCE's earnings and cash flows. The ERRA review proceeding is also used as a venue to review costs in various memorandum and balancing accounts including the Grid Hardening Balancing Account.
FERC
Transmission capital and operating costs that are prudently incurred, including a return on its net investment in transmission assets, are recovered through revenue authorized by the FERC. Since 2012, SCE has used a formula rate to determine SCE's FERC transmission revenue requirement, including its construction work in progress revenue requirement. Under operation of the formula rate, transmission revenue will be updated to actual cost of service annually. The transmission revenue requirement and rates are updated each December, to reflect a forecast of costs for the upcoming rate period, as well as a true up of the transmission revenue to actual costs incurred by SCE in the prior calendar year on its formula rate.
The FERC ROE is currently fixed at 10.3% and does not separately reflect any adders. The FERC ROE would only change if a different ROE is approved by the FERC in a new proceeding. For further information on the FERC formula rates, related transmission revenue requirements and rate changes, see "MD&A—Liquidity and Capital Resources—SCE—Regulatory Proceedings—2026 FERC Formula Rate Annual Update."
127
Table of Contents
Retail Rates Structure and Residential Rate Design
To develop retail rates, the authorized revenue requirements are allocated among all customer classes (residential, commercial, industrial, agricultural and street lighting) on a functional basis (i.e., generation, distribution, transmission, etc.). Specific rate components are designed to recover the authorized revenue allocated to each customer class.
SCE has a two-tier residential rate structure. The first tier is priced below the average rate and is intended to cover the customer's essential electricity needs. The second tier is priced at 29% more than the first tier. SCE's current default rate is the time of use ("TOU") structure, which incorporates the two-tier structure through a baseline credit applied to approximately 300 kWh a month. Under a TOU rate structure, rates are based on the time of day and the season. TOU rates are typically lower early in the day, overnight, and on the weekends when energy resources are less in demand. As of December 31, 2025, approximately 60% of residential customers are on TOU rates. To recover fixed costs that SCE incurs to serve a residential customer regardless of the customer’s usage, SCE assesses both a minimum charge of $10 per month ($5 for low-income customers) and a fixed charge.
In May 2024, the CPUC authorized a residential class Basic Service Charge (i.e., fixed charge) with three levels dependent on participation in income-qualified programs. Customers enrolled in the California Alternative Rates for Energy (CARE) and Family Electric Rate Assistance (FERA) programs receive Basic Service Charges that are respectively 25% and 50% of the $24.15 fixed charge applicable to all other residential customers. SCE began including the new Basic Service Charge on residential customer bills in the fourth quarter of 2025. For information on residential rates for customers with renewable generation systems, see "—Competition" below.
Purchased Power and Fuel Supply
SCE obtains the power, energy, and local grid support needed to serve its customers primarily from purchases from external parties. SCE estimates that approximately 15% of power delivered to SCE's customers in 2025 came from SCE's own generating facilities.
Natural Gas Supply
SCE requires natural gas to fuel its Mountainview and peaker plants, which are generation units that operate in response to wholesale market signals related to power prices and reliability needs. The physical natural gas purchased by SCE is sourced in competitive interstate markets at trading points on the SoCalGas local distribution company system. SoCalGas is the primary provider of intrastate pipeline transportation service to the gas-fueled generation stations that SCE controls. In 2015 – 2016, SoCalGas experienced a significant natural gas fuel leak at its Aliso Canyon underground gas storage facility that resulted in reduced capacity and usage of the facility. Currently, Aliso Canyon is authorized to operate at up to 79% of its maximum capacity. CPUC has established a biennial assessment process to evaluate the reliability and cost impacts of minimizing or eliminating reliance on Aliso Canyon. To date, SCE has found that gas storage-use restrictions combined with SoCalGas pipeline maintenance constraints contributed to increased electricity costs for customers but did not impact grid reliability. However, there is no certainty that these restrictions or pipeline constraints will not impact grid reliability in the future. Price increases faced by customers would not affect SCE's earnings because SCE expects recovery of these costs through the ERRA balancing account or other CPUC approved procurement plans. However, these higher prices may impact cash flow due to the timing of those recoveries. For more information on cost-recovery mechanisms, see "—Overview of Ratemaking Process" above. SCE is actively monitoring legislative and regulatory processes that are addressing pipeline and electric grid operations impacted by the Aliso Canyon leak, including the CPUC’s biennial assessment process for considering changes to the facility's maximum inventory. SCE has also made additional procurement efforts to alleviate the impact of the partial closure of Aliso Canyon, including accelerating existing contracts for new capacity, procuring energy storage from third-parties, contracting for design, build, and transfer of utility-owned storage, procuring additional demand response and contracting for firm gas transportation capacity.
CAISO Wholesale Energy Market
The CAISO operates a wholesale energy market primarily in California through which competing electricity generators offer their electricity output to market participants, including electricity retailers. The CAISO schedules power in hourly increments with hourly prices through a day-ahead market in California and schedules power in fifteen-minute and five-minute increments with fifteen-minute and five-minute prices through two real-time markets that cover California and portions of ten neighboring states through the Western Energy Imbalance Market. Both markets optimize energy procurement, ancillary service procurement, unit commitment and congestion management. SCE participates in the day-ahead and real-time markets for the sale of its own generation and generation under contract and for purchases for its load requirements. In December 2023, the FERC approved an Extended Day-Ahead Market ("EDAM"), giving utilities outside the CAISO the option of joining a centralized day-ahead market run by the CAISO. The EDAM, which is currently scheduled to go-live in May 2026, gives utilities an opportunity to lock in energy prices a day in advance, and thereby substantially avoid volatility in the real-time energy market.
128
Table of Contents
The CPUC's Resource Adequacy program imposes resource adequacy requirements on load-serving entities like SCE that are designed to provide sufficient resources to the CAISO to ensure the safe and reliable operation of the grid in real time. All load-serving entities are responsible for meeting the system resource adequacy requirements for the load they serve, plus an additional amount that is referred to as a planning reserve margin. The CPUC has also adopted a central procurement structure in SCE's distribution service area for local resource adequacy that transfers the responsibility for procuring local resource adequacy from other local load-serving entities to SCE as a central procurement entity ("CPE") for its distribution service area. Under this structure, while SCE procures local resource adequacy to meet the local resource adequacy requirement for its distribution service area, other load-serving entities can also procure their own local resources. Load-serving entities ("LSE") that procure their own local resources can sell the capacity to the CPE, and utilize the resources.
Following state-wide rotating outages in August 2020 that impacted a significant number of SCE's customers, the CPUC has taken action towards ensuring reliable electric service in the event that extreme heat events occur during summer. The CPUC has issued decisions requiring at least an aggregate of 15,500 MW of additional net qualifying renewable or zero-emitting capacity to be procured collectively by all of the load-serving entities subject to the CPUC’s Integrated Resource Planning purview. The aggregate additional capacity is required by 2028, with 2,000 MW required by 2023, an additional 6,000 MW required by 2024, an additional 1,500 MW required by 2025, an additional 2,000 MW required by 2026, an additional 2,000 MW required by 2027, and an additional 2,000 MW of long-lead time resources, comprised of 1,000 MW of long-duration storage and 1,000 MW of firm zero-emitting resources required by 2028; 2,500 MW of the aggregate procurement requirement through 2025 must be through generation or generation paired with storage.
SCE's allocation of the requirements is 705 MW by 2023, 2,114 MW by 2024, 529 MW by 2025, 684 MW by 2026, 684 MW by 2027, and 705 MW of long-lead time resources, comprised of 353 MW of long-duration storage and 352 MW of firm zero-emitting resources by 2028, for a total of 5,421 MW; 880 MW of the aggregate procurement requirement through 2025 must be through generation or generation paired with storage.
As of December 31, 2025, SCE has executed sufficient long‑term contracts to meet all of these procurement requirements, including renewable and zero‑emitting resources, long‑duration storage and geothermal resources. In addition, SCE has executed contracts sufficient to meet its 880 MW procurement requirement for generation or generation paired with storage due in 2025, although certain projects are not expected to achieve commercial operation until 2026 or 2027. In September 2025, the CPUC established conditions under which delayed procurement may still be deemed compliant for up to three years after a required online date if the LSE has executed sufficient long‑term contracts and meets their month‑ahead system resource adequacy obligations during the delay. SCE expects to utilize this alternative compliance mechanism to address remaining delays in meeting applicable procurement requirements.
In February 2024, the CPUC adopted a decision approving SCE’s integrated resource plan identifying the resources needed to meet California’s greenhouse gas emissions and reliability targets and authorizing SCE to procure the resource needs identified in its plan. Additionally, the CPUC approved a process to request extensions of the 2028 procurement requirement for long-duration storage and firm zero-emitting resources to no later than 2031.
Competition
SCE faces retail competition in the sale of electricity to the extent that federal and California laws permit other sources to provide electricity and related services to retail customers within SCE's service area. While retail competition impacts customer rates it does not impact SCE's earnings activities because the volume of electricity sales is decoupled from authorized revenue. The increased retail competition is from governmental entities formed by cities, counties, and certain other public agencies to generate and/or purchase electricity for their local residents and businesses, known as CCAs. While California law provides only limited opportunities for customers in SCE's service area to choose to purchase power directly from an Electric Service Provider, a limited, phased-in expansion of customer choice ("Direct Access") for nonresidential customers was authorized beginning in 2009, and an additional limited expansion of Direct Access was authorized in 2018. When a customer who had previously taken bundled service from SCE converts to taking retail electricity service from an Electric Service Provider or a CCA, SCE remains that customer's transmission and distribution provider. Other forms of departing load include customer generation, and load that departs SCE service entirely to take electricity service from a publicly owned utility or a tribal utility.
California law requires bundled service customers to remain financially indifferent to departing load customers and to the mass return of departing load customers in the event of an Electric Service Provider or CCA's failure or other service termination. The CPUC has issued a series of decisions designed to avoid cost shifting in the context of departing load, including revising the power charge indifference adjustment methodology to effectively address potential cost shifts to bundled service customers.
Investor-owned utilities serve as the default providers of last resort in their respective service areas and can be significantly impacted by Electric Service Providers or CCAs failing or otherwise exiting the market. In March 2021, the CPUC initiated
129
Table of Contents
a rulemaking to examine the risks of catastrophic failures by Electric Service Providers or CCAs on investor-owned utilities and the need for any changes in the regulatory framework to increase consumer protections and financial security requirements, among other measures. In 2024, the CPUC issued a decision adopting changes to CCA financial security requirements, CCA financial reporting requirements, among others. As part of Phase 2 of this rulemaking, the CPUC will also examine under what requirements a CCA or Electric Service Provider may assume the provider of last resort obligation from an investor-owned electric utility in some or all of the utility’s service area.
As of year-end 2025, SCE had twelve CCAs serving customers in its service area that represented approximately 21% of SCE's total service load. One CCA expanded in SCE's service area in 2025. One expanded CCA has been approved by the CPUC to serve customers in SCE's service area in 2026. Based on recent load statistics, SCE anticipates that Direct Access and CCA load will be approximately 15% and 21% of its total service load by the end of 2026, respectively.
Customer-owned power generation and storage alternatives, such as rooftop solar facilities and battery systems, are increasingly installed by SCE's customers behind SCE's revenue meter as a result of technological developments, federal and state subsidies, and declining costs of such alternatives. Beginning in 2020, and subject to certain exceptions, most newly built homes in California are required to have solar installations.
Net Energy Metering
California legislation passed in 1995 encouraged private residential and commercial investment in renewable energy resources by requiring SCE and other investor-owned electric utilities to offer a NEM billing option to customers who install eligible power generation systems to supply all or part of their energy needs. NEM customers are interconnected to SCE's grid and credited for the net difference between the electricity SCE supplied to them through the grid and the electricity the customer exported to SCE over a 12-month period. SCE is required to credit the NEM customer for most of the power they sell back to SCE at the retail rate. Through the credit they receive, NEM customers effectively avoid paying certain grid-related costs. NEM customers are also exempted from some non-bypassable, standby and departing load charges and interconnection fees. Electric Service Providers and CCAs may, but are not required by law to, offer NEM rates.
In January 2016, the CPUC issued a decision adopting a new standard NEM tariff for customers with renewable generation systems. The changes that the CPUC decision made to the existing NEM tariff did not significantly impact the NEM subsidy. Specifically, the decision required customers that take service on SCE's NEM tariff after June 2017 to continue to be compensated at the retail rate, minus certain non-bypassable charges. NEM customers also continued to be exempted from standby and departing load charges but were required to pay a $75 interconnection fee and to select a time-of-use retail rate.
In August 2020, the CPUC initiated a rulemaking to develop a successor to the NEM tariffs. In December 2022, the CPUC issued a final decision adopting a Net Billing Tariff ("NBT") that decoupled export compensation from the retail rate, which lowers the subsidy compared to NEM. Under the final decision, the CPUC deferred consideration of whether to assess a grid participation charge to address the costs participating customers avoid by reducing the electricity they purchase from SCE and whether to adopt other mechanisms that would allow SCE to recover its cost of service and the costs of many public policy programs to another pending proceeding. The final decision also provides an enhanced subsidy for lower income customers and customers who pair rooftop solar with energy storage systems. The final decision does not apply to existing NEM customers until after they have completed twenty years on their existing NEM tariff, at which time they will move to the new, reduced NBT tariff. Non-utility parties' appeal of the CPUC's final decision is pending.
The effect of these types of competition on SCE generally is to reduce the amount of electricity purchased from SCE by retail customers. Customers who use alternative electricity sources typically continue to use and pay for SCE's transmission and distribution services; however, current NEM customers use, but do not pay the full cost for, those services. While changes in volume or rates generally do not impact SCE's earnings activities, decreased retail electricity sales by SCE has the effect of increasing utility rates because the costs of the distribution grid are not currently borne by all customers that benefit from its use. In November 2025, a Base Service Charge authorized by the CPUC was implemented for residential rates. The Base Service Charge recovers a portion of the fixed costs of providing service. See "Risk Factors—Risks Relating to Southern California Edison Company—Competitive and Market Risks."
In the area of transmission infrastructure, SCE has experienced increased competition from independent transmission providers under the FERC's transmission planning requirements rules, effective in 2011, that removed the incumbent public utility transmission owners' federally-based right of first refusal to construct certain new transmission facilities and mandated regional and interregional transmission planning. Regional entities, such as independent system operators, have processes for regional and interregional transmission planning and the competitive solicitation and selection of developers (including incumbent utilities) to build and own certain types of new transmission projects. The CAISO has held competitive solicitations pursuant to these rules and independent service providers were selected.
130
Table of Contents
Properties
SCE supplies electricity to its customers through extensive transmission and distribution networks. Its transmission facilities, which are located primarily in California but also in Nevada and Arizona, deliver power from generating sources to the distribution network and consist of approximately 13,000 circuit-miles of lines ranging from 55 kV to 500 kV and approximately 80 transmission substations. SCE's distribution system, which takes power from distribution substations to customers, consists of approximately 38,000 circuit-miles of overhead lines, approximately 32,000 circuit-miles of underground lines and approximately 730 distribution substations.
At December 31, 2025, SCE had ownership interests in generating and energy storage facilities, primarily located in California, with approximately 7,000 MW of net physical capacity, of which SCE's pro-rata share is approximately 3,500 MW. SCE's pro rata share includes approximately 70 MW of capacity from facilities that were not operational or out of service at December 31, 2025 and excludes retired facilities. In addition, SCE owns two utility storage facilities in SCE’s service area with an aggregate capacity of 312.5 MW and a third 225 MW facility is expected to be in-service in 2026.
Certain of SCE's substations, and portions of its transmission, distribution and communication systems are located on lands owned by the federal, state or local governments pursuant to licenses, permits, easements or leases, or on public streets or highways pursuant to franchises. Certain of the documents evidencing such rights obligate SCE, under specified circumstances and at its expense, to relocate such transmission, distribution, and communication facilities located on lands owned or controlled by federal, state, or local governments.
SCE owns and operates hydroelectric plants and related reservoirs, which are located on private lands and U.S.-owned lands and are subject to FERC licenses. The majority of these plants have FERC licenses that expire at various times through 2046. FERC licenses impose numerous restrictions and obligations on SCE, including the right of the United States to acquire projects upon payment of specified compensation. When a FERC license expires, SCE must obtain a new license or shut down, and FERC may reissue the license, often with stricter conditions or award it to a competing applicant that offers a superior proposal. New FERC hydroelectric licenses generally impose stricter environmental requirements, longer and more structured pre-application processes, and greater stakeholder involvement compared to older licenses, reflecting updated laws that prioritize environmental protection and resource management. In addition, SCE expects additional opposition to new licenses by environmental stakeholder groups. If, in the future, SCE decides to, or is forced to, decommission one or more hydroelectric projects, the costs related to the decommissioning will be substantial. The CPUC approved SCE recovering a portion of estimated decommissioning costs for hydroelectric projects in the 2021 and 2025 GRCs. SCE intends to sell, subject to regulatory approval, a portion of its hydroelectric facilities comprising of approximately 17 MW of capacity by 2027.
Substantially all of SCE's properties are subject to the lien of a trust indenture securing first and refunding mortgage bonds. See "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
Seasonality
Due to warm weather during the summer months and SCE's rate design, operating revenue during the third quarter of each year is generally higher than the other quarters. However, as discussed above, SCE earnings are not affected by changes in retail electricity sales. See "—Overview of Ratemaking Process" above.
SOUTHERN CALIFORNIA WILDFIRES
Unprecedented weather conditions in California due to climate change, greater concentrations of residents in high-fire risk areas and insufficient hardening of homes and other structures have contributed to wildfires, including those where SCE's equipment has been alleged to be associated with the fire's ignition, that have caused loss of life and substantial damage in SCE's service area, including in January 2025. Multiple factors have contributed to increased wildfire activity and faster progression of wildfires across SCE's service area and in other areas of California in recent years. These include the buildup of dry vegetation in areas severely impacted by years of historic drought, lack of adequate clearing of hazardous fuels by responsible parties, higher temperatures, lower humidity, increased incidence of dry lightning, and strong Santa Ana winds. At the same time that wildfire risk has been increasing in Southern California, residential and commercial development has occurred and is occurring in some of the highest-risk areas. Such factors can increase the likelihood and extent of damage caused by wildfires. SCE has determined that approximately 27% of its service area is in areas identified as high fire risk, and SCE's service area remains susceptible to additional wildfire activity.
In response to worsening conditions and wildfire activity in its service area, SCE has been, and will continue to be, focused on developing and implementing plans aimed at reducing the risk of SCE equipment contributing to the ignition of wildfires. In addition, California must also continue to increase its investment in wildfire prevention and fire suppression capabilities.
131
Table of Contents
Multiple lawsuits related to wildfire events have been initiated against SCE and Edison International. For further information, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides," "Risk Factors" and "Management Overview—Southern California Wildfires and Mudslides" in the MD&A.
Recovery of Wildfire-Related Costs
Pre-AB 1054 Cost Recovery
California courts have previously found investor-owned utilities to be strictly liable for property damage, regardless of fault, by applying the theory of inverse condemnation when a utility's facilities were determined to be a substantial cause of a wildfire that caused the property damage. The rationale stated by these courts for applying this theory to investor-owned utilities is that property damages resulting from a public improvement, such as the distribution of electricity, can be spread across the larger community that benefited from such improvement through recovery of uninsured wildfire-related costs in electric rates. The CPUC has resolved only one litigated proceeding addressing the extent to which inverse condemnation-related costs are recoverable in electric rates for fires pre-dating the passage of AB 1054. That decision, issued in November 2017, denied SDG&E's request to include in its rates uninsured wildfire-related costs arising from several 2007 wildfires, finding that SDG&E did not meet the prudency standard because it did not prudently manage and operate its facilities prior to or at the outset of the 2007 wildfires. In July 2018, the CPUC denied both SDG&E's application for rehearing on its cost recovery request and a joint application for rehearing filed by SCE and PG&E limited to the applicability of inverse condemnation principles in the same proceeding. The California Court of Appeal, the California Supreme Court and the United States Supreme Court denied SDG&E's petitions for review of the CPUC's denial of SDG&E's application.
California Wildfire Legislation
In July 2019, AB 1054 provided for a revised prudency standard and the initial account to fund the Wildfire Fund for the benefit of the three California investor-owned utilities participating in the fund, PG&E, SCE and SDG&E. In September 2025, SB 254 supplemented the Wildfire Fund by establishing a new Continuation Account within the Wildfire Fund, which may provide up to $18 billion of additional funding for the Wildfire Fund. The summary of the wildfire legislation below and elsewhere within this report is based on SCE's interpretation of AB 1054 and SB 254.
Clarified Prudency Standard
The CPUC must apply a revised framework when assessing the prudency of a utility in connection with a request for recovery of wildfire costs for wildfires ignited after July 12, 2019. The CPUC is required to find a utility to be prudent if the utility's conduct related to the ignition was consistent with actions that a reasonable utility would have undertaken under similar circumstances, at the relevant point in time, and based on the information available at that time. Prudent conduct is not limited to the optimum practice, method, or act to the exclusion of others, but rather encompasses a spectrum of possible practices, methods, or acts consistent with utility system needs, the interest of ratepayers, and the requirements of governmental agencies. The CPUC may determine that wildfire costs may be recoverable, in whole or in part, by taking into account factors within and outside the utility's control, including winds, humidity, temperature, emergency response, evacuation timing and availability of firefighting resources. Further, utilities with a valid safety certification will be presumed to have acted prudently related to a wildfire ignition unless a party in the cost recovery proceeding creates serious doubt as to the reasonableness of the utility's conduct, at which time, the burden shifts back to the utility to prove its conduct was prudent. If a utility does not have a valid safety certification, it will have the burden to prove, based on a preponderance of evidence, that its conduct was prudent. The new prudency framework will survive the termination of the Wildfire Fund.
Utilities participating in the Wildfire Fund that are found to be prudent are not required to reimburse the fund for amounts withdrawn from the fund. Participating utilities can request recovery of wildfire costs through electric rates if the fund has been exhausted.
Wildfire Fund
The California Wildfire Legislation provides for the Wildfire Fund to reimburse a participating utility for payment of third-party damages claims arising from certain wildfires that exceed, in aggregate in a calendar year, the greater of $1.0 billion or the insurance coverage required to be maintained under the California Wildfire Legislation. The Wildfire Fund is available for claims related to wildfires that are determined by the responsible government investigatory agency or a court to have been caused by a utility or are asserted to have been caused by a utility and result in a court-approved dismissal resulting from the settlement of third-party damage claims. The Initial Account is available for claims related to wildfires ignited after July 12, 2019 and the Continuation Account may become available for claims related to wildfires ignited after the SB 254 Effective Date.
132
Table of Contents
SCE and SDG&E collectively made initial contributions totaling approximately $2.7 billion (SCE share is $2.4 billion) to the Initial Account in September 2019. Upon its emergence from bankruptcy, on July 1, 2020, PG&E made its initial contribution of approximately $4.8 billion to the Initial Account. PG&E, SCE and SDG&E are also collectively expected to make aggregate contributions of approximately $3.0 billion (SCE share is $950 million) to the Initial Account through annual contributions to the fund over a 10-year period by no later than January 1 of each year, of which they have made seven annual contributions totaling approximately $2.1 billion (SCE share is approximately $665 million). In addition to PG&E's, SCE's and SDG&E's contributions to the Initial Account, PG&E, SCE and SDG&E are expected to collect $6.1 billion, $6.1 billion and $1.3 billion, respectively, from their customers over a 15-year period through a dedicated rate component. The amount collected from customers may be directly contributed to the Wildfire Fund or used to support the issuance of up to $10.5 billion in bonds by the California Department of Water Resources, the proceeds of which would be contributed to the fund. In addition to funding contributions to the Wildfire Fund, the amount collected from utility customers will pay for, among other things, any interest and financing costs related to any bonds that are issued by the California Department of Water Resources to support the contributions to the Wildfire Fund.
In September 2025, the Wildfire Fund was supplemented by establishing the Continuation Account to potentially provide up to $18 billion of additional funding. As described below, the Continuation Account will be funded contingent upon certain conditions. Once all claims under the Initial Account are resolved and no further claims are anticipated, any remaining assets in the Initial Account will be transferred to the Continuation Account.
If the administrator of the Wildfire Fund determines, on or before December 31, 2028, that annual contributions to the fund are required and the CPUC subsequently extends the non-bypassable charge imposed on customers until January 1, 2046, the Continuation Account will be funded by a combination of contributions from customers and the three participating investor-owned utilities.
Upon the CPUC's decision to extend the non-bypassable charge, PG&E's, SCE's, and SDG&E's customers will be required to contribute an aggregate of $9 billion through a dedicated rate component. The dedicated rate component collected from customers will be directly contributed to the Continuation Account or used to support the issuance of up to $9 billion in bonds by the California Department of Water Resources, the proceeds of which would be contributed to the fund. In addition to funding contributions to the Continuation Account, the amount collected from utility customers will pay for, among other things, any interest and financing costs related to any bonds that are issued by the California Department of Water Resources to support the contributions to the fund.
In addition to customer contributions, PG&E, SCE, and SDG&E have agreed, if required, to contribute an aggregate of $300 million annually (SCE's share is $143.6 million) from 2029 through 2045 for a total aggregate contribution of approximately $5.1 billion. In addition, if the administrator determines that the Continuation Account requires additional contributions, PG&E, SCE, and SDG&E will contribute an additional $780 million annually (SCE's share is $373.2 million) over a five-year period for a total aggregate additional contribution of approximately $3.9 billion (the "Contingent Contribution"). If the administrator terminates the Continuation Account prior to the final installment of the Contingent Contribution, one-half of the remaining unpaid installment payments will be credited to customer rates.
SCE's contributions to the Wildfire Fund are not recoverable through electric rates and will be excluded from the measurement of SCE's CPUC-jurisdictional authorized capital structure. SCE will also not be entitled to cost recovery for any borrowing costs incurred in connection with its contributions to the Wildfire Fund. For information on the accounting impact of SCE's contributions to the Wildfire Fund see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—Wildfire Fund " in this report.
Reimbursement from Wildfire Fund and Liability Cap
Until the fund administrator determines that the fund will be terminated, participating investor-owned utilities are expected to be reimbursed from the Wildfire Fund for eligible claims, on a first come, first served basis, subject to the fund administrator's review. SCE will reimburse the fund for any withdrawn amounts if SCE receives payment of such amounts under an indemnification agreement or from an insurance provider or other third-party. SCE will also be required to reimburse the fund for withdrawn amounts that the CPUC disallows, subject to the Liability Cap. If the utility has maintained a valid safety certification and its actions or inactions that resulted in the wildfire are not found to constitute conscious or willful disregard of the rights and safety of others, the aggregate requirement to reimburse the fund over a trailing three calendar year period is capped at 20% of the equity portion of the utility's transmission and distribution rate base for the year of ignition. The California Wildfire Legislation also permits reimbursement obligations for disallowed costs to be offset with SCE’s contributions to the Continuation Account, but not the Initial Account. Based on SCE's weighted-average 2025 transmission and distribution rate base, excluding general plant and intangibles, and using the equity portion of SCE's CPUC authorized capital structure of 52%, SCE's requirement to reimburse the Wildfire Fund for fires ignited in 2025, i.e. the Eaton Fire, is capped at approximately $4.3 billion.
133
Table of Contents
SCE will not be allowed to recover borrowing costs incurred to reimburse the fund for amounts that the CPUC disallows. The Wildfire Fund and, consequently, the Liability Cap will terminate when the administrator determines that the fund has been exhausted.
Excluded Capital Expenditures
As required by California Wildfire Legislation, SCE has excluded approximately $1.6 billion of spending on wildfire risk mitigation capital expenditures made after August 1, 2019 from its rate base and also expects to exclude approximately $2.9 billion of wildfire risk mitigation capital expenditures approved on or after January 1, 2026. SCE can apply for irrevocable orders from the CPUC to finance these capital expenditures, including through the issuance of securitized bonds, and can recover any prudently incurred financing costs.
Securitization of Amounts that Exceed Initial Account
For fires ignited between January 1, 2025 and September 19, 2025, if the Initial Account is exhausted, participating utilities may, before seeking a prudency review, directly apply for a CPUC financing order to authorize the recovery of eligible claims that exceed amounts available in the Initial Account through fixed recovery charges. However, if the CPUC determines that the costs were not prudently incurred, participating utilities will be required to return any amounts recovered back to customers over a period that matches the remaining duration of the financing instrument through credits to customer rates.
Subrogation Settlements
For wildfires ignited on or after the SB 254 Effective Date that destroy 1,000 or more structures, property insurers must first offer subrogation rights to the utility before selling to third parties. The utility has 30 days to respond. If accepted, the insurer must release further claims against the utility for that fire.
Safety Certification and Wildfire Mitigation Plan
Under the California Wildfire Legislation, SCE can obtain an annual safety certification upon approval by the OEIS of certain requirements, including an approved WMP. SCE was also required to submit a comprehensive WMP to the CPUC at least once every three years for review and approval. Each such comprehensive plan was required to cover at least a three-year period. Future changes introduced by SB 254 will align four-year GRC and WMP cycles, providing for reforms to each SCE's preliminary WMP to conform to the revenue authorized in the GRC. SCE expects it will be required to submit a comprehensive WMP to OEIS covering a four-year period in future cycles.
On December 11, 2024, the OEIS issued SCE's 2024 safety certification which will remain in effect until the OEIS acts on SCE's 2025 safety certification request which was submitted on December 2, 2025. Once issued, SCE’s 2025 safety certification will be valid for 12 months from the date of issuance and will remain effective until the subsequent approval process is complete. SCE submitted its 2026 – 2028 WMP in May 2025 and a draft decision approving the 2026 – 2028 WMP was released by the OEIS in December 2025. A final decision on SCE's 2026 – 2028 WMP is expected in the first quarter of 2026.
Public Safety Power Shutoffs
In addition to the investments SCE is making as part of its WMP, SCE also uses Public Safety Power Shutoffs ("PSPS") to proactively de-energize power lines as a last resort to mitigate the risk of catastrophic wildfires during extreme weather events.
In June 2021, the CPUC issued a final decision which, among other things, will reduce future authorized revenue for the volumetric reductions in electricity sales resulting from PSPS events initiated after June 2021 until the CPUC determines that improvements in the PSPS program have been made.
In June 2022, the SED issued an Administrative Enforcement Order ("AEO") against SCE proposing penalties of $10 million for alleged noncompliance with customer notification requirements related to PSPS events in 2020. In October 2022, the SED and SCE reached a settlement agreement under which SCE agreed to a penalty of $7 million, inclusive of a $6 million disallowance of PSPS program-related costs. SCE also agreed to complete certain corrective actions to resolve the AEO. SCE certified completion of the AEO corrective actions in June 2023. SCE did not admit wrongdoing or liability as part of the settlement.
In April 2023, the SED issued a Notice of Violation to SCE for noncompliance with customer notification and other CPUC requirements related to PSPS events in 2021. In November 2024, the CPUC approved an Administrative Consent Order and Agreement between SED and SCE to resolve all issues involving the 2021 PSPS events, resulting in financial penalties totaling $2.4 million.
134
Table of Contents
SCE initiated PSPS 14 times in 2025 resulting in approximately 1.4 billion customer minutes interrupted. Of the 2025 PSPS events, two were initiated in January 2025, resulting in approximately 1.0 billion customer minutes interrupted primarily in Los Angeles, Riverside, San Bernardino, and Ventura counties under conditions of severe windstorm events. In June 2025, the SED issued a Notice of Violation to SCE for noncompliance with customer notification and other CPUC requirements relating to PSPS events in January 2025 and in December 2025, issued a PSPS citation proposing financial penalties of $7.9 million. SCE agreed to accept the penalty in January 2026.
SCE has made and continues to make significant investments and progress in improving its PSPS protocols, including through increased automation of customer notifications. However, SCE may be subject to additional penalties for noncompliance with customer notification and post event reporting requirements related to PSPS events.
ENVIRONMENTAL CONSIDERATIONS
Greenhouse Gas Regulation
Edison International recognizes that its industry and the global economy are in the midst of a profound transformation toward a low-carbon future as a response to climate change. SCE plans to be a key enabler of the adoption of new energy technologies that benefit its customers. See "Management Overview—Electricity Industry Trends" in the MD&A.
Using preliminary estimates based on information available as of February 11, 2026, approximately 73% of SCE's sources of utility-owned generation were carbon-free in 2025. SCE estimates that approximately 18% of power delivered to SCE's customers in 2025 came from SCE's own generating facilities, with approximately 9% nuclear, 4% large hydroelectric, less than 1% small hydroelectric, and less than 1% solar generation. Approximately 5% were natural gas sources. Since 2010, SCE has reported its annual GHG emissions from utility-owned generation each year to the U.S Environmental Protection Agency by March 31 of the following year. SCE's 2025 GHG emissions from utility-owned generation are estimated to be approximately 1.6 million metric tons of carbon dioxide equivalents.
California is committed to reducing its GHG emissions, improving local air quality and supporting continued economic growth. California's major initiatives for reducing GHG emissions include a law that targets the reduction of GHG emissions across the entire state economy to 40% below 1990 levels by 2030 and a California cap-and-trade program established by the California Air Resources Board ("CARB"). Other major policy measures include the Low Carbon Fuel Standard program established by CARB. In 2025, the California legislature authorized the CARB to extend the program through 2045 and rebrand it "Cap-and Invest." In 2022, the California Climate Crisis Act declared the policy of the state to achieve net zero greenhouse gas emissions as soon as possible, but no later than 2045, to achieve and maintain net negative greenhouse gas emissions thereafter, and to ensure that by 2045, statewide anthropogenic greenhouse gas emissions are reduced to at least 85% below the 1990 levels. Edison International is committed to achieving net-zero GHG emissions by 2045, in alignment with economy-wide climate actions planned by California. This commitment covers the power SCE delivers to customers and Edison International's enterprise-wide operations.
In the California cap-and invest (previously the cap-and-trade) program, all covered GHG emitters, including SCE, are subject to an annually declining program "cap" on emissions designed to encourage entities to reduce emissions from their operations. Covered entities must remit a compliance instrument for each ton of carbon dioxide equivalent gas emitted and can do so buying state-issued emission allowances at auction or purchasing them in the secondary allowance market. From 2013 to 2020, GHG emitters could have met up to 8% of their cap-and-trade obligations by procuring GHG offset credits from verified offset programs, such as reforestation, that have recognized effects on reducing atmospheric GHGs. The offset usage limit has decreased to 4% for 2021 – 2025 emissions and will then increase to 6% for 2026 – 2030 emissions. Starting with 2021 emissions, no more than one-half of the quantitative offset usage limit may be sourced from projects that do not provide direct environmental benefits in California. New legislation extending the program directs CARB to conform its cap-and-invest covered sector emissions to statutory targets: 40% below 1990 GHG levels by 2030 and net zero GHG emissions by 2045, and maintains offset limits at 6% for 2026 through 2045.
California has adopted RPS targets that require California retail sellers of electricity to provide certain percentages of energy sales from renewable resources defined in the statute, including 33% of retail sales by December 2020; 44% of retail sales by December 2024, 52% of retail sales by December 2027, and 60% of retail sales by December 2030. Approximately 35% of SCE's supply portfolio in 2020 came from renewable sources eligible under California's RPS, of which 32% was delivered to customers and 3% was sold for resale. As such, SCE met California's 2020 RPS target. Approximately 38% of SCE's supply portfolio in 2024 came from renewable sources eligible under California's RPS, of which 35% was delivered to customers and 3% was sold for resale. With the use of excess procurement from prior years, as allowed under the RPS program, SCE met California’s 44% RPS requirement for 2024. SCE's climate change objectives align with California's requirements. Separate from RPS targets, California requires the following percentages of retail sales of electricity to California end-use customers must be from carbon-free resources by the following deadlines: 90% by December 31, 2035, 95% by December 31, 2040, and 100% by December 31, 2045. California also requires each state agency to ensure that carbon-free resources supply 100% of electricity procured on its behalf by December 31, 2035. SCE
135
Table of Contents
plans to propose for CPUC approval new programs to help state agency customers meet their accelerated 100% clean power needs. Using preliminary estimates based on information available as of February 11, 2026, approximately 61% of SCE's customer deliveries in 2025 came from carbon-free resources.
Additionally, the CPUC and the California Energy Commission adopted GHG emission performance standards that apply to California investor-owned and publicly owned utilities' long-term arrangements for the purchase of electricity. The standards prohibit these entities, including SCE, from owning or entering into long-term financial commitments with generators, such as coal plants, that emit more GHG than a combined-cycle natural gas turbine generator. California also supports climate action to meet the December 2015 Paris Agreement.
Edison International supports these California environmental initiatives and has undertaken analysis which, consistent with third-party analysis, shows that electrification across multiple sectors, including transportation and industrial sectors, is among the most cost-effective ways to achieve California's requirements and goals. Edison International and SCE believe that these initiatives will lead to increased electrification across the economy and SCE is investing in grid technologies and charging infrastructure to support California's goals.
Environmental Risks
Climate change has, and continues to, impact California. According to the National Centers for Environmental Information, since 1980, California has faced 46 weather-related disasters costing over $1 billion each. In 2024, the Earth experienced its hottest year on record. This spike in temperature is making extreme weather events commonplace, with ripple effects that put people around the world in harm’s way. Severe droughts and windstorms contributed to the devastating wildfires that swept through parts of California in recent years, demonstrating the serious threat that weather extremes caused by climate change pose to California's communities and the environment. See "Management Overview—Southern California Wildfires and Mudslides" in the MD&A and "Business—Southern California Wildfires."
Severe weather events, including drought, increasingly severe windstorms and rising sea-levels, pose risks to SCE's infrastructure and SCE and Edison International are investing in building a more resilient grid to reduce climate- and weather-related vulnerabilities. See "Liquidity and Capital Resources—SCE—Regulatory Proceedings—Wildfire Related Regulatory Proceedings" in the MD&A.
In May 2022, SCE provided its climate adaptation vulnerability assessment ("CAVA") to the CPUC. The CAVA addresses the projected climate impacts of temperature, sea level, precipitation, wildfire, and cascading impacts (such as rain on snow or debris flow) on SCE in the 2030, 2050, and 2070 timeframes. SCE's CAVA will inform planning related to SCE assets, operations, and services, with the goal of maintaining a resilient electric grid in the face of climate change and will inform future investment in the grid. SCE plans to file its next CAVA concurrent with its RAMP application in May 2026.
For more information on risks related to climate change, environmental regulation and SCE's business strategy, see "Risk Factors—Risks Relating to Southern California Edison Company—Operating Risks."
UNRESOLVED STAFF COMMENTS
None.
CYBERSECURITY
Overview
Cybersecurity presents an ever-evolving challenge to the electric power industry and Edison International and SCE have identified cybersecurity as a key enterprise risk. SCE's operations require the continuous availability of critical information and operational technology systems, sensitive customer and employee data, and infrastructure information, all of which are targets for malicious actors. Cyber attacks, which can arise from external actors, internal threats, or through SCE's supply chain, are continually becoming more frequent and more sophisticated. SCE's grid modernization efforts and the transition to a more connected grid, including incorporating communication and operating technologies aimed at enabling SCE to respond faster, operate its systems more efficiently and reliably, and incorporate DERs at a greater level, also increases SCE’s vulnerability to cybersecurity attacks. To SCE's knowledge it has not experienced a material cybersecurity incident to date.
SCE’s increased reliance on technology necessarily increases cybersecurity risk. Cybersecurity incidents that may cause a major disruption of SCE's operations, and therefore may materially affect Edison International and SCE's financial condition, operations, and business reputation, include cyber attacks designed to compromise or exfiltrate data (e.g., ransomware attacks), damage or destroy systems, interrupt availability, conduct future malicious actions, and/or gain control of or otherwise interrupt the operation of SCE’s electric grid. For additional information on risks from cybersecurity threats that may have a material effect on Edison International and SCE, see "Risk Factors—Risks Relating to Edison International and Southern California Edison Company—Cybersecurity and Physical Security Risks."
136
Table of Contents
Risk Management, Strategy and Oversight
SCE assesses and monitors cybersecurity risks to current infrastructure, new projects, and third parties, including vendors. SCE maintains incident response plans, utilizes cybersecurity incident response exercises, performs targeted audits, leverages third party assessments and uses the National Institute of Standards and Technology ("NIST") Cybersecurity Framework ("CSF") as a guideline to identify, evaluate and manage material risks from cybersecurity threats. SCE also engages consultants, and coordinates with the Federal government and industry peers, to assist in identifying, evaluating and managing its cybersecurity risks, and uses contractual terms to establish cybersecurity requirements with certain third parties. Identified cybersecurity risks are documented and presented to management to review and advise on cybersecurity strategies and mitigation measures. Based on management reviews, cybersecurity strategies and remediation plans are developed or adjusted to address pertinent risks. Edison International and SCE leverage training, policies, technical and procedural controls, and mitigation plans to address risks from cybersecurity threats.
Management has established a cybersecurity oversight group comprised of a multidisciplinary senior management team, including its Vice President of Enterprise Risk Management, to monitor and provide strategic direction for the prevention, detection, mitigation, and remediation of risks from cybersecurity threats. A Boards of Directors’ liaison regularly attends meetings of the cybersecurity oversight group and provides reports to the Safety and Operations Committees of the Boards of Directors. Other members of the Boards of Directors are invited to attend meetings and typically attend at least one meeting annually.
The Edison International and SCE Audit and Finance Committees of the Boards of Directors oversee enterprise risk management, including risks from cybersecurity threats. Annually, Edison International and SCE’s enterprise risk management team conducts a review of enterprise risks, including risks from cybersecurity threats, and presents the results of its review to management and the Audit and Finance Committees. In addition, the Boards of Directors have assigned primary responsibility for cybersecurity operations oversight to the Edison International and SCE Safety and Operations Committees, which receive semi-annual cybersecurity updates from SCE’s Chief Security Officer on specific topics, including the dynamic cybersecurity landscape and defense and risk mitigation strategies. To inform its oversight over cybersecurity threats, SCE’s Chief Security Officer also presents to the full Boards of Directors annually. The Boards of Directors also receive a periodic cybersecurity report from an external SCE consultant that includes an assessment of SCE's cybersecurity program and organization.
SCE’s Chief Security Officer has primary responsibility for assessing and managing risks from cybersecurity threats, and serves as Edison International and SCE’s chief information security officer. SCE’s Chief Security Officer has extensive experience in the cybersecurity industry, including previous experience in cybersecurity roles at Southern Company, the MITRE Corporation, NIST, and the Federal Bureau of Investigation. SCE's Chief Security Officer earned a bachelor’s degree in computer information systems from Clemson University and is a Certified Information Systems Security Professional.
For additional information on the Edison International Board of Directors cybersecurity related experience and oversight of cybersecurity risk management, see Edison International’s Proxy Statement under the headings "Director Skills Matrix" and "Oversight of Strategy, Risk and Sustainability."
PROPERTIES
As a holding company, Edison International does not directly own any significant properties other than the stock of its subsidiaries. The principal properties of SCE are described above under "Business—SCE—Properties."
LEGAL PROCEEDINGS
2017/2018 Wildfire/Mudslide Events
The lawsuits related to the 2017/2018 Wildfire/Mudslide Events naming SCE as a defendant have been filed by three categories of plaintiffs: individual plaintiffs, subrogation plaintiffs and public entity plaintiffs. A number of the lawsuits also name Edison International as a defendant and some of the lawsuits were filed as purported class actions. As of February 11, 2026, in addition to the outstanding claims of approximately 100 claims of approximately 15,000 initial individual plaintiffs, there were alleged and potential claims of certain public entity plaintiffs, including CAL OES, outstanding. SCE has settled all fire suppression and subrogation plaintiffs' claims related to the 2017/2018 Wildfire/Mudslide Events, except for one indemnification claim. The litigation could take a number of years to be completely resolved because of the complexity of the matters and number of plaintiffs. The statutes of limitations for individual plaintiffs in the 2017/2018 Wildfire/Mudslide Events have expired.
As of February 11, 2026, SCE was aware of approximately 13 pending unsettled lawsuits representing approximately 26 individual plaintiffs related to the Thomas and Koenigstein Fires and the Montecito Mudslides naming SCE as a defendant. Approximately 7 of the approximately 13 lawsuits also name Edison International as a defendant based on its
137
Table of Contents
ownership and alleged control of SCE. One of the lawsuits was filed as a purported class action. The court has denied class certification in the one lawsuit that was filed as a purported class action and plaintiffs have appealed the denial. The lawsuits, which have been filed in the superior courts of Ventura, Santa Barbara and Los Angeles Counties allege, among other things, negligence, inverse condemnation, trespass, private nuisance, and violations of the public utilities and health and safety codes. SCE and certain of the individual plaintiffs in the Thomas and Koenigstein Fire litigation have been pursuing settlements of claims under a mediation program adopted to promote an efficient and orderly settlement process. As of February 11, 2026, two damages only trials have been set for May and July 2026 for two individual plaintiff households in the TKM litigation.
As of February 11, 2026, SCE was aware of approximately 30 currently pending unsettled lawsuits representing approximately 60 individual plaintiffs related to the Woolsey Fire naming SCE as a defendant. Approximately 20 of the 30 lawsuits also name Edison International as a defendant based on its ownership and alleged control of SCE. The lawsuits, which have been filed in the superior courts of Ventura and Los Angeles Counties allege, among other things, negligence, inverse condemnation, personal injury, wrongful death, trespass, private nuisance, and violations of the public utilities and health and safety codes. SCE and certain of the individual plaintiffs in the Woolsey Fire litigation have been pursuing settlements of claims under a mediation program adopted to promote an efficient and orderly settlement process. As of February 11, 2026, a trial has been set for CAL OES in July 2026 and four damages only trials have been set for July 2026 and August 2026.
The Thomas and Koenigstein Fires and Montecito Mudslides lawsuits are being coordinated in the Los Angeles Superior Court. The Woolsey Fire lawsuits have also been coordinated in the Los Angeles Superior Court.
Eaton Fire
In January 2025, several wind-driven wildfires impacted portions of SCE's service area, causing loss of life, substantial damage and service outages for SCE customers. One of the largest of these wildfires, the Eaton Fire, ignited in SCE's service area in Los Angeles County and spread due to a number of contributing factors under conditions of an extreme Santa Ana windstorm.
Multiple lawsuits related to the Eaton Fire have been initiated against SCE. A number of the lawsuits also name Edison International as a defendant and some of the lawsuits were filed as purported class actions. As of February 11, 2026, SCE was aware of approximately 1,500 currently pending unsettled lawsuits related to the Eaton Fire: representing lawsuits by approximately 20,000 individual plaintiffs, lawsuits by subrogation plaintiffs and lawsuits by public entity plaintiffs, including the United States of America, the County of Los Angeles, the City of Pasadena and the City of Sierra Madre, related to the Eaton Fire. A bellwether jury trial has been set for January 2027. In January 2026, SCE filed a cross-complaint against certain public and private entities whose actions or inaction may have caused, contributed to or exacerbated the losses that resulted from the fire.
For information on the 2017/2018 Wildfire/Mudslide Events and the Eaton Fire, see "Notes to Consolidated Financial Statements—Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides" in this report.
Environmental Proceedings
Each of Edison International and SCE have elected to disclose environmental proceedings described in Item 103(c)(3)(iii) of Regulation SK unless it reasonably believes that such proceeding will result in no monetary sanctions, or in monetary sanctions, exclusive of interest and costs, of less than $1 million.
Mission Canyon
SCE performed 1.6 miles of access road grading and vegetation clearing in the Mission Canyon area of Santa Barbara County in December 2019, resulting in debris moving downslope into a creek bed and other impacts in the area (the "Mission Canyon Incident"). Several state and federal environmental agencies and the County and City of Santa Barbara have investigated the unpermitted grading and discharges to the creek, and SCE has received Notices of Violation from the Army Corps of Engineers, the County of Santa Barbara, the California Department of Fish & Wildlife and the Regional Water Quality Control Board. In December 2020, SCE and the Santa Barbara County District Attorney entered into a settlement regarding alleged criminal and civil violations related to the Mission Canyon Incident. Under the settlement, SCE pled no contest to a single misdemeanor charge for violation of the California Water Code and agreed to pay a $10,000 fine. SCE also agreed to pay a civil penalty of $3.5 million and is subject to an injunction requiring completion of planned remediation work and compliance with environmental regulations. The remediation work is expected to be completed in early 2026, after which the site will enter a minimum five-year monitoring and maintenance period to ensure project success and satisfy the remaining injunctive requirements. It is presently unknown whether any regulatory agencies will impose additional fines or penalties on SCE with respect to the Mission Canyon Incident and, if so, in what amounts. SCE does not expect fines or penalties that are imposed in connection with the Mission Canyon Incident to be material.
138
Table of Contents
MINE SAFETY DISCLOSURE
Not applicable.
CERTAIN INFORMATION ABOUT EDISON INTERNATIONAL
INFORMATION ABOUT OUR EXECUTIVE OFFICERS
Executive OfficerAge at
February 18, 2026		Company Position
Pedro J. Pizarro60President and Chief Executive Officer
Maria Rigatti62Executive Vice President and Chief Financial Officer
Chonda J. Nwamu
55
Executive Vice President and General Counsel
Caroline Choi57
Executive Vice President, Public Policy and Corporate Affairs
Natalie K. Schilling66Senior Vice President and Chief Human Resources Officer
Erica S. Bowman
48
Vice President, Strategy, Planning and Performance
Steven D. Powell47President and Chief Executive Officer, SCE
Jill C. Anderson45Executive Vice President and Chief Operating Officer, SCE
J. Andrew Murphy65
President and Chief Executive Officer, Trio
As set forth in Article IV of Edison International's Bylaws, the elected officers of Edison International are chosen annually by, and serve at the pleasure of, the Edison International Board of Directors and hold their respective offices until their resignation, removal, other disqualification from service, or until their respective successors are elected. All of the officers of Edison International have been actively engaged in the business of Edison International and its subsidiaries for more than five years, except for Ms. Nwamu, and have served in their present positions for the periods stated below. Additionally, those officers who have had other or additional principal positions in the past five years had the following business experience during that period:
139
Table of Contents
Executive OfficersCompany PositionEffective Dates
Pedro J. Pizarro
President and Chief Executive Officer, Edison International
October 2016 to present
Maria RigattiExecutive Vice President and Chief Financial Officer, Edison InternationalOctober 2016 to present
Chonda J. Nwamu
Executive Vice President and General Counsel, Edison International
Executive Vice President, General Counsel and Secretary, Ameren Corporation1
Senior Vice President, General Counsel, and Secretary, Ameren Corporation1
April 2025 to present
March 2023 to April 2025
August 2019 to February 2023
Caroline Choi
Executive Vice President, Public Policy & Corporate Affairs, Edison International and SCE
Senior Vice President, Corporate Affairs and Public Policy, Edison International and SCE
Senior Vice President, Corporate Affairs, Edison International and SCE
March 2025 to present

February 2024 to March 2025

February 2019 to February 2024
Natalie K. SchillingSenior Vice President and Chief Human Resources Officer, Edison International and SCE
Vice President, Human Resources, SCE
March 2022 to present

April 2020 to February 2022
Erica S. Bowman
Vice President, Strategy, Planning and Performance, Edison International and SCE
Managing Director, Regulatory Policy and Strategic Analysis, SCE
Director, CEO's Office, Edison International		February 2024 to Present
August 2022 to February 2024
November 2020 to July 2022
Steven D. Powell
President and Chief Executive Officer, SCE
Executive Vice President, Operations, SCE
December 2021 to present
September 2019 to December 2021
Jill C. AndersonExecutive Vice President and Chief Operating Officer, SCE
Senior Vice President, Customer Service, SCE		December 2021 to present
March 2020 to December 2021
J. Andrew Murphy
President and Chief Executive Officer, Trio
Senior Vice President, Strategy and Corporate Development, Edison International
July 2023 to present
September 2015 to July 2023
1Ameren Corporation is a St. Louis-based public utility holding company, and is not a parent, affiliate or subsidiary of Edison International
DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Information concerning executive officers of Edison International is set forth above under "Information about our Executive Officers." Other information responding to this section will appear in the Edison International Proxy
Statement under the headings "Our Director Nominees," "Director Skills Matrix," "Director Biographies," and is incorporated herein by this reference.
Code of Ethics
The Edison International Employee Code of Conduct is applicable to all officers and employees of Edison International and its subsidiaries. The Code is available on Edison International's Internet website at edisoninvestor.com at "Corporate Governance." Any amendments or waivers of Code provisions for the Company's principal executive officer, principal financial officer, principal accounting officer or controller, or persons performing similar functions, will be posted on Edison International's Internet website at edisoninvestor.com.
Insider Trading Policy and Procedures
Edison International has adopted an insider trading policy that governs the purchase, sale and other dispositions of all securities of Edison International and its subsidiaries by Edison International and SCE directors, officers, employees and certain third parties. The adopted policy is designed to promote compliance with insider trading laws, rules and regulations, and any listing standards applicable to Edison International and SCE.
140
Table of Contents
The insider trading policy also restricts trading and other transactions for a limited group of covered persons who include Edison International and SCE directors, executive officers, and certain employees whose duties involve access to material non-public information, to defined window periods that follow the Edison International and SCE quarterly earnings releases. A copy of Edison International's insider trading policy is filed with this Annual Report on Form 10-K as Exhibit 19. In addition, with regard to the Edison International trading in its own securities, it is Edison International’s policy to comply with the federal securities laws and the applicable exchange listing requirements.
EXECUTIVE COMPENSATION
Information responding to this section will appear in the Edison International Proxy Statement under the headings "Compensation Discussion and Analysis," "Executive Compensation" (other than "—Pay Versus Performance”) and "Director Compensation" and is incorporated herein by this reference.
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
Information responding to this section will appear in the Edison International Proxy Statement under the heading "Stock Ownership" and is incorporated herein by this reference.
Equity Compensation Plan Information
All of Edison International's equity compensation plans that were in effect as of December 31, 2025 have been approved by security holders. The following table sets forth, for each of Edison International's equity compensation plans, the number of shares of Edison International Common Stock subject to outstanding options, warrants and rights to acquire such stock, the weighted average exercise price of those outstanding options, warrants and rights, and the number of shares remaining available for future award grants as of December 31, 2025.
Plan CategoryNumber of securities to
be issued upon exercise
of outstanding options,
 warrants and rights
(a)		Weighted average
exercise price of
outstanding options,
warrants and rights
(b)		Number of securities remaining for
future issuance under equity
compensation plans (excluding
securities reflected in column
(a)(c)
Equity compensation plans approved by security holders
11,888,0771
$62.91
24,599,2992
1This amount includes 9,884,521 shares covered by outstanding stock options, 1,086,706 shares covered by outstanding restricted stock unit awards, 221,118 shares covered by outstanding deferred stock unit awards, and 695,731 shares covered by outstanding performance share awards (calculated at 100% of the target number of shares subject to each performance share award; the actual payout for each award will be zero to twice the target number of shares for the award, depending on performance), with the outstanding shares covered by outstanding restricted stock unit, deferred stock unit, and performance share awards including the crediting of dividend equivalents through December 31, 2025. The weighted average exercise price of awards outstanding under equity compensation plans approved by security holders reflected in column (b) above is calculated based on the outstanding stock options under these plans as the other forms of awards outstanding have no exercise price. Awards payable solely in cash are not reflected in this table.
2This amount is the aggregate number of shares available for new awards under the Edison International 2007 Performance Incentive Plan and the Edison International Employee Stock Purchase Plan as of December 31, 2025, consisting of 21,799,220 shares and 2,800,079 shares, respectively. The maximum number of shares of Edison International Common Stock authorized for issuances or transfers pursuant to awards under the Edison International 2007 Performance Incentive Plan is 82,500,000. Shares available under the Edison International 2007 Performance Incentive Plan may generally, subject to certain limits set forth in the plan, be used for any type of award authorized under that plan, including stock options, restricted stock, performance shares, restricted or deferred units, and stock bonuses. The maximum number of shares of Edison International Common Stock authorized under the Edison International Employee Stock Purchase Plan is 3,000,000.
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
Information responding to this section will appear in the Edison International Proxy Statement under the headings "Governance Structure and Processes—Certain Relationships and Related Party Transactions," and "Governance Structure and Processes—Director Independence," and is incorporated herein by this reference.
PRINCIPAL ACCOUNTANT FEES AND SERVICES
PricewaterhouseCoopers LLP ("PwC") served as Edison International's and SCE's principal accountant in 2025. Information responding to this section for Edison International will appear in the Edison International Proxy Statement under the heading "Independent Auditor Fees," and is incorporated herein by this reference.
141
Table of Contents
The following table sets forth the aggregate fees billed by PwC to SCE for the fiscal years ended December 31, 2025 and 2024:
SCE ($000)
Type of Fee20252024
Audit Fees1
$6,029 $6,026 
Audit-Related Fees2
175 15 
Tax Fees3
260 247 
All Other Fees4
582 632 
Total$7,046 $6,920 
1Represent fees for professional services provided in connection with the audit of SCE's annual financial statements and reviews of SCE's quarterly financial statements and for services regularly provided by PwC in connection with regulatory filings or engagements.
2These represent fees for assurance and related services related to the performance of the audit or review of the financial statements and not reported under "Audit Fees" above.
3Represent fees for tax-related compliance and other tax-related services to support compliance with federal and state tax reporting and payment requirements, including tax return review and review of tax laws, regulations or case precedent.
4Represent fees for miscellaneous services. "All Other Fees" included fees for attestation services related to a CPUC required report on wildfire memorandum accounts and to securitizations for the years ended December 31, 2025 and 2024.
The SCE Audit and Finance Committee annually approves all proposed audit fees in executive session without PwC present, considering several factors, including a breakdown of the services to be provided, proposed staffing and hourly rates, and changes in SCE and industry from the prior year. The audit fees are the culmination of a process which included a comparison of the prior year's proposed fees to actual fees incurred and fee proposals for known and anticipated 2025 services in the audit, audit-related, tax and other categories. The committee's deliberations consider balancing the design of an audit scope that will achieve a high-quality audit with driving efficiencies from both SCE and PwC while compensating PwC fairly.
The SCE Audit and Finance Committee is required to pre-approve all audit and permitted non-audit services performed by PwC to ensure these services will not impair the firm's independence. The SCE Audit and Finance Committee has delegated to the Committee Chair the authority to pre-approve services between committee meetings, provided that any pre-approval decisions are presented to the committee at its next meeting. PwC must assure that all audit and non-audit services provided to SCE have been approved by the SCE Audit and Finance Committee.
During the fiscal year ended December 31, 2025, all services performed by PwC were pre-approved by the SCE Audit and Finance Committee, irrespective of whether the services required pre-approval under the Securities Exchange Act of 1934.
142
Table of Contents
MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
Edison International
Edison International Common Stock is traded on the New York Stock Exchange under the symbol "EIX."
There are restrictions on the ability of SCE to transfer funds to Edison International that materially limit the ability of Edison International to pay cash dividends. Such restrictions are discussed in "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends." The number of common stockholders of record of Edison International was 22,624 on February 11, 2026. In addition, Edison International cannot pay dividends if it does not meet California law requirements on retained earnings and solvency.
Southern California Edison Company
As a result of the formation of a holding company described under the heading "Business" above, all of the issued and outstanding common stock of SCE is owned by Edison International and there is no market for such stock. There are restrictions on SCE's ability to pay dividends to Edison International and to its preference shareholders. Such restrictions are discussed in "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends."
Purchases of Equity Securities by Edison International and Affiliated Purchasers
The following table contains information about all purchases of Edison International's Series A Preferred Stock, Series B Preferred Stock, and common stock made by or on behalf of Edison International in the fourth quarter of 2025. For further information about Edison International's Series A Preferred Stock, Series B Preferred Stock and common stock repurchase programs, see "Notes to Consolidated Financial Statements—Note 14. Equity."
PeriodSeries
(a) Total Number of Shares (or Units Purchased)
(b) Average Price Paid per Share (or Unit)
(c) Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs1 2
(d) Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs
October 1, 2025 to October 31, 2025
Series A Preferred Stock—— ——
Series B Preferred Stock—— ——
Common Stock
657$58.00 657$42,768,392 
November 1, 2025 to November 30, 2025Series A Preferred Stock————
Series B Preferred Stock————
Common Stock452$58.71 452$42,741,856 
December 1, 2025 to December 31, 2025
Series A Preferred Stock744,975 $1,014.63 744,975—
Series B Preferred Stock415,517 $1,008.61 415,517—
Common Stock
111$58.23 111$42,735,393 
TotalSeries A Preferred Stock744,975 $1,014.63 744,975—
Series B Preferred Stock415,517 $1,008.61 415,517—
Common Stock1,220$58.28 1,220$42,735,393 
1Purchases were made pursuant to Edison International's 2025 common stock repurchase program disclosed in the 2024 10-K.
143
Table of Contents
2On November 20, 2025, Edison International commenced a tender offer to purchase its outstanding 5.00% Fixed-Rate Reset Cumulative Perpetual Preferred Stock, Series B ("Series B Preferred Stock") and its 5.375% Fixed-Rate Reset Cumulative Perpetual Preferred Stock, Series A ("Series A Preferred Stock"), plus accrued dividends (“Tender Offer”). The Tender Offer expired on December 19, 2025 and Edison International purchased, upon the terms and subject to the conditions described in the Schedule TO filed with the SEC on November 20, 2025, as amended, $415,517,000 aggregate liquidation preference of Series B Preferred Stock shares and $744,975,000 aggregate liquidation preference of Series A Preferred Stock shares.
Comparison of Five-Year Cumulative Total Return
53
At December 31,
202020212022202320242025
Edison International100114111130150119
S & P 500 Index100129105133166196
PHLX Utility Sector Index
100118119108131153
Note: Assumes $100 invested on December 31, 2020, in stock or index including reinvestment of dividends. Performance of the PHLX Utility Sector Index is regularly reviewed by management and the Board of Directors in understanding Edison International's relative performance and is used in conjunction with elements of Edison International's compensation program.
OTHER INFORMATION
Insider Trading Arrangements
On October 31, 2025, Peter Taylor, chair of the Edison International Board of Directors, adopted a Rule 10b5-1 trading arrangement that is intended to satisfy the affirmative defense of Rule 10b5-1(c) of the Exchange Act for the sale of up to 4,000 shares of Edison International’s Common Stock. The first date that sales of any shares permitted to be sold under the trading arrangement is March 2, 2026 and subsequent sales under the trading arrangement may occur on a regular basis until December 1, 2027.
PART II, ITEM 6. Reserved.
This item no longer requires disclosure.
FORM 10-K SUMMARY
None.
DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
Not applicable.
144
Table of Contents
EXHIBITS AND FINANCIAL STATEMENT SCHEDULES (Part IV, Item 15)
(a) (1) Financial Statements
See Consolidated Financial Statements listed in the Table of Contents of this report.
(a) (2) Report of Independent Registered Public Accounting Firm and Schedules Supplementing Financial Statements
Edison International
The following documents may be found in this report at the indicated page numbers under the headings "Financial Statements and Supplementary Data—Reports of Independent Registered Accounting Firm" and "Exhibits and Financial Statement Schedules—Schedules Supplementing Financial Statements" in the Table of Contents of this report.
Report of Independent Registered Public Accounting Firm - Edison International
Schedule I – Condensed Financial Information of Edison International Parent
Schedules II through V, inclusive, for Edison International are omitted as not required or not applicable.
Southern California Edison Company
The following documents may be found in this report at the indicated page numbers under the headings "Financial Statements and Supplementary Data—Reports of Independent Registered Accounting Firm" and "Exhibits and Financial Statement Schedules—Schedules Supplementing Financial Statements" in the Table of Contents of this report.
Report of Independent Registered Public Accounting Firm - SCE
Schedules I through V, inclusive, for SCE are omitted as not required or not applicable.
(a) (3) Exhibits
145
Table of Contents
EXHIBIT INDEX
Exhibit
Number		Description
Edison International
3.1
Certificate of Restated Articles of Incorporation of Edison International, effective December 19, 2006, together with all Certificates of Determination of Preference of Preferred Stock issued since December 19, 2006 (File No. 1-9936, filed as Exhibit 3.1 to Edison International's Form 10-K for the year ended December 31, 2021)*
3.2
Bylaws of Edison International, as amended effective, December 8, 2022 (File No. 1-9936, filed as Exhibit No. 3.1 to Edison International's Form 8-K dated December 8, 2022 and filed December 9, 2022)*
Southern California Edison Company
3.3
Certificate of Amended and Restated Articles of Incorporation of Southern California Edison Company, effective August 28, 2023 (Filed No. 1-2313 filed as Exhibit 3.1 to SCE’s Form 8-K dated September 19, 2023 and filed September 21, 2023)*
3.4
Bylaws of Southern California Edison Company, as amended effective December 8, 2022 (File No. 1-2313, filed as Exhibit No. 3.2 to SCE's Form 8-K dated December 8, 2022 and filed December 9, 2022)*
Edison International
4.1
Edison International - Description of Registered Securities (File No. 1-9936, filed as Exhibit 4.1 to Edison International's Form 10-K for the year ended December 31, 2019)*
4.2
Senior Indenture, dated September 10, 2010 (File No. 1-9936, filed as Exhibit 4.1 to Edison International's Form 10-Q for the quarter ended September 30, 2010)*
4.3
4.4
Form of Certificate representing Series A Preferred Stock (included as Exhibit A to Certificate of Determination of the 5.375% Fixed Rate Reset Cumulative Perpetual Preferred Stock Series A) (File No. 1-9936, filed as Exhibit 3.1 to Edison International's Form 10-K for the year ended December 31, 2021)*
4.5
Form of Certificate representing Series B Preferred Stock (included as Exhibit A to Certificate of Determination of the 5.00% Fixed Rate Reset Cumulative Perpetual Preferred Stock Series B) (File No. 1-9936, filed as Exhibit 3.1 to Edison International's Form 10-K for the year ended December 31, 2021)*
Southern California Edison Company
146
Table of Contents
Exhibit
Number		Description
4.6
Southern California Edison Company First Mortgage Bond Trust Indenture, dated as of October 1, 1923 (File No. 1-2313, filed as Exhibit 4.2 to SCE's Form 10-K for the year ended December 31, 2010)*
4.7
Southern California Edison Company Indenture, dated as of January 15, 1993 (File No. 1-2313, filed as Exhibit 4.3 to SCE's Form 10-K for the year ended December 31, 2017)*
4.8
Certificate of Determination of Preferences of the Company’s Series M Preference Stock (File No. 1-2313, filed as Exhibit 4.1 to SCE’s Form 8-K dated November 16, 2023 and filed on November 22, 2023)*
4.9
Edison International and Southern California Edison Company
10.1**
Edison International 2008 Director Deferred Compensation Plan, as amended and restated effective January 1, 2021 (File No. 1-9936, filed as Exhibit No. 10.2 to Edison International's Form 10-Q for the quarter ended September 30, 2020)*
10.2**
Edison International Executive Deferred Compensation Plan, as amended and restated effective June 19, 2014 (as amended) (File No. 1-9936, filed as Exhibit No. 10.7 to Edison International's Form 10-Q for the quarter ended March 31, 2018)*
10.3**
Edison International 2008 Executive Deferred Compensation Plan, as amended and restated effective January 1, 2025 (File No. 1-9936, filed as Exhibit 10.3 to Edison International’s Form 10-K for the year ended December 31, 2024)*
10.4**
Southern California Edison Company Executive Retirement Plan, as amended effective June 19, 2014 (File No. 1-9936, filed as Exhibit 10.7 to Edison International and SCE's Form 10-Q for the quarter ended June 30, 2014)*
10.5 **
Edison International 2008 Executive Retirement Plan, as amended and restated effective August 27, 2025 (File No. 1-9936, filed as Exhibit 10.2 to Edison International’s Form 10-Q for the quarter ended September 30, 2025)*
10.6**
Edison International Executive Incentive Compensation Plan, as amended and restated effective January 1, 2025 (File No. 1-9936, filed as Exhibit 10.5 to Edison International’s Form 10-K for the year ended December 31, 2024)*
10.7**
Edison International 2008 Executive Disability Plan, as amended and restated effective January 1, 2025 (File No. 1-9936, filed as Exhibit 10.6 to Edison International’s Form 10-K for the year ended December 31, 2024)*
10.8**
Edison International 2007 Performance Incentive Plan, as amended and restated effective April 24, 2025 (incorporated by reference from the Appendix to Edison International’s Definitive Proxy Statement on Schedule 14A filed on March 14, 2025)*
10.8.1**
Edison International 2016 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.4 to Edison International's Form 10-Q for the quarter ended March 31, 2016)*
147
Table of Contents
Exhibit
Number		Description
10.8.2**
Edison International 2017 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.2 to Edison International's Form 10-Q for the quarter ended March 31, 2017)*
10.8.3**
Edison International 2018 Long-Term Incentives Terms and Conditions (File. No. 1-9936, filed as Exhibit 10.3 to Edison International's Form 10-Q for the quarter ended March 31, 2018)*
10.8.4**
Edison International 2019 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.3 to Edison International's Form 10-Q for the quarter ended March 31, 2019)*
10.8.5**
Edison International 2020 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.4 to Edison International's Form 10-Q for the quarter ended March 31, 2020)*
10.8.6**
Edison International 2021 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended March 31, 2021)*
10.8.7**
Edison International 2022 Long-Term Incentives Terms and Conditions (File, No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended March 31, 2022)*
10.8.8**
Edison International 2023 Long-Term Incentives Terms and Conditions (File No. 1-9936, filed as Exhibit 10.1 to Edison International’s Form 10-Q for the quarter ended March 31, 2023)*
10.8.9**
10.8.10**
10.9**
Edison International 2008 Executive Severance Plan, as amended and restated effective February 26, 2025 (Filed No. 1-9936, filed as Exhibit 10.3 to Edison International’s Form 10-Q for the quarter ended March 31, 2025)*
10.10**
Edison International and Southern California Edison Company Director Compensation Schedule as adopted August 28, 2025 (File No. 1-9936, filed as Exhibit 10.1 to Edison International’s Form 10-Q for the quarter ended September 30, 2025)*
10.11**
Edison International Director Matching Gifts Program, as revised effective January 1, 2019 (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 10-Q for the quarter ended September 30, 2019)*
10.12
Amended and Restated Agreement for the Allocation of Income Tax Liabilities and Benefits among Edison International, Southern California Edison Company and The Mission Group dated September 10, 1996 (File No. 1-9936, filed as Exhibit 10.3 to Edison International's Form 10-Q for the quarter ended September 30, 2002)*
10.13
Amended and Restated Tax-Allocation Agreement among The Mission Group and its first-tier subsidiaries dated September 10, 1996 (File No. 1-9936, filed as Exhibit 10.3.1 to Edison International's Form 10-Q for the quarter ended September 30, 2002)*
148
Table of Contents
Exhibit
Number		Description
10.13.1
Amended and Restated Tax-Allocation Agreement between Mission Energy Holding Company and Edison Mission Energy dated February 13, 2012 (File No. 333-68630, filed as Exhibit 10.11 to Edison Mission Energy's Form 10-K for the year ended December 31, 2011)*
10.13.2
Modification No. 1 to the Amended and Restated Tax-Allocation Agreement between Mission Energy Holding Company and Edison Mission Energy dated February 13, 2012 (File No. 333-68630, filed as Exhibit 10.1 to Edison Mission Energy's Form 8-K dated November 15, 2012 and filed November 21, 2012)*
10.13.3
Amended and Restated Administrative Agreement Re Tax Allocation Payments, dated February 13, 2012, among Edison International and subsidiary parties. (File No. 333-68630, filed as Exhibit 10.12 to Edison Mission Energy's Form 10-K for the year ended December 31, 2011)*
10.14**
Form of Indemnity Agreement between Edison International and its Directors and any officer, employee or other agent designated by the Board of Directors (File No. 1-9936, filed as Exhibit 10.5 to Edison International's Form 10-Q for the quarter ended June 30, 2005)*
10.15
Second Amended and Restated Credit Agreement dated as of May 17, 2018 among Edison International, the several banks and other financial institutions from time to time parties thereto, the several agents parties thereto and JPMorgan Chase Bank, N.A., as administrative agent for the lenders. (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 8-K dated and filed May 18, 2018)*
10.16
First Amendment, dated as of April 30, 2021, to the Second Amended and Restated Credit Agreement, dated as of May 17, 2018, by and among Edison International, the several banks and other financial institutions party thereto and JPMorgan Chase bank, N.A., as administrative agent. (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 8-K dated April 30, 2021 and filed May 6, 2021)*
10.17
Second Amendment, dated as of May 4, 2022, to the Second Amended and Restated Credit Agreement, dated as of May 17, 2018, as amended by the First Amendment, dated as of April 30, 2021, by and among Edison International, the several banks and other financial institutions party thereto and JPMorgan Chase Bank, N.A., as administrative agent (File No. 1-9936, filed as Exhibit 10.1 to Edison International's Form 8-K dated and filed May 4, 2022)*
10.18
Third Amendment, dated as of May 3, 2023, to the Second Amended and Restated Credit Agreement dated as of May 17, 2018, as amended by the First Amendment, dated as of April 30, 2021 and the Second Amendment, dated as of May 4, 2022, by and among Edison International, the several banks and other financial institutions party thereto and JPMorgan Chase Bank, N.A., as administrative agent (File No. 1-9936, filed as Exhibit 10.1 to Edison International’s Form 10-Q for the quarter ended June 30, 2023)*
10.19
Second Amended and Restated Credit Agreement dated as of May 17, 2018 among SCE, the several banks and other financial institutions from time to time parties thereto, the several agents parties thereto and JPMorgan Chase Bank, N.A., as administrative agent for the lenders. (File No. 1-2313, filed as Exhibit 10.2 to SCE's Form 8-K dated and filed May 18, 2018)*
10.20
First Amendment, dated as of April 30, 2021, to the Second Amended and Restated Credit Agreement, dated as of May 17, 2018, by and among Southern California Edison Company, the several banks and other financial institutions party thereto and JPMorgan Chase bank, N.A., as administrative agent. (File No. 1-2313, filed as Exhibit 10.2 to SCE's Form 8-K dated April 30, 2021 and filed May 6, 2021)*
149
Table of Contents
Exhibit
Number		Description
10.21
Commitment Increase Supplement, by and among Southern California Edison Company and the lenders named therein, and accepted by JPMorgan Chase Bank, N.A., as administrative agent and the issuing lenders named therein. (File No. 1-2313, filed as Exhibit 10.3 to SCE's Form 8-K dated April 30, 2021 and filed May 6, 2021)*
10.22
Second Amendment, dated as of May 4, 2022, to the Second Amended and Restated Credit Agreement, dated as of May 17, 2018, as amended by the First Amendment, dated as of April 30, 2021, as supplemented by the Commitment Increase Supplement, dated as of April 30, 2021, by and among Southern California Edison Company, the several banks and other financial institutions party thereto and JPMorgan Chase Bank, N.A., as administrative agent (File No. 1-2313, filed as Exhibit 10.2 to SCE's Form 8-K dated and filed May 4, 2022)*
10.23
Third Amendment, dated as of May 3, 2023, to the Second Amended and Restated Credit Agreement dated as of May 17, 2018, as amended by the First Amendment, dated as of April 30, 2021 and the Second Amendment, dated as of May 4, 2022, by and among Southern California Edison, the several banks and other financial institutions party thereto and JPMorgan Chase Bank, N.A., as administrative agent (File No. 1-2313, filed as Exhibit 10.2 to SCE’s Form 10-Q for the quarter ended June 30, 2023)*
10.24
10.25
19.1
21.1
Subsidiaries of the Registrants
23.1
Consent of Independent Registered Public Accounting Firm (Edison International)
23.2
Consent of Independent Registered Public Accounting Firm (Southern California Edison Company)
24.1
Powers of Attorney of Edison International and Southern California Edison Company
24.2
Certified copies of Resolutions of Boards of Edison International and Southern California Edison Company Directors Authorizing Execution of SEC Reports
31.1
Certifications of the Chief Executive Officer and Chief Financial Officer of Edison International pursuant to Section 302 of the Sarbanes-Oxley Act
31.2
Certifications of the Chief Executive Officer and Chief Financial Officer of Southern California Edison Company pursuant to Section 302 of the Sarbanes-Oxley Act
150
Table of Contents
Exhibit
Number		Description
32.1
Certifications of the Chief Executive Officer and the Chief Financial Officer of Edison International required by Section 906 of the Sarbanes-Oxley Act
32.2
Certifications of the Chief Executive Officer and the Chief Financial Officer of Southern California Edison Company required by Section 906 of the Sarbanes-Oxley Act
97.1
Edison International and Southern California Edison Company Incentive Compensation Recoupment Policy For Accounting Restatements, as amended effective October 2, 2023 (File No. 1-9936, filed as Exhibit 97.1 to Edison International’s Form10-K for the year ended December 31, 2023)*
101.1
Financial statements from the annual report on Form 10-K of Edison International for the year ended December 31, 2025, filed on February 18, 2026, formatted in Inline XBRL: (i) the Consolidated Statements of Income; (ii) the Consolidated Statements of Comprehensive Income; (iii) the Consolidated Balance Sheets; (iv) the Consolidated Statements of Cash Flows; (v) Consolidated Statements of Changes in Equity and (vi) the Notes to Consolidated Financial Statements
101.2
Financial statements from the annual report on Form 10-K of Southern California Edison Company for the year ended December 31, 2025, filed on February 18, 2026, formatted in Inline XBRL: (i) the Consolidated Statements of Income; (ii) the Consolidated Statements of Comprehensive Income; (iii) the Consolidated Balance Sheets; (iv) the Consolidated Statements of Cash Flows; (v) Consolidated Statements of Changes in Equity and (vi) the Notes to Consolidated Financial Statements
104The cover page of this report formatted in Inline XBRL (included as Exhibit 101)

*Incorporated by reference pursuant to Rule 12b-32.
**Indicates a management contract or compensatory plan or arrangement, as required by Item 15(a)(3).
Edison International and SCE will furnish a copy of any exhibit listed in the accompanying Exhibit Index upon written request and upon payment to Edison International or SCE of their reasonable expenses of furnishing such exhibit, which shall be limited to photocopying charges and, if mailed to the requesting party, the cost of first-class postage.
151
Table of Contents
SCHEDULES SUPPLEMENTING FINANCIAL STATEMENTS
EDISON INTERNATIONAL
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
CONDENSED BALANCE SHEETS

December 31,
(in millions)20252024
Assets:
Cash and cash equivalents$1 $4 
Other current assets567 606 
Total current assets568 610 
Investments in subsidiaries23,276 20,630 
Deferred income taxes834 760 
Other long-term assets98 67 
Total assets$24,776 $22,067 
Liabilities and equity:
Short-term debt$1,354 $445 
Current portion of long-term debt— 800 
Other current liabilities676 639 
Total current liabilities2,030 1,884 
Long-term debt4,815 4,268 
Other long-term liabilities352 350 
Total equity17,579 15,565 
Total liabilities and equity$24,776 $22,067 
152
Table of Contents
EDISON INTERNATIONAL
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
CONDENSED STATEMENTS OF INCOME
For the Years Ended December 31, 2025, 2024 and 2023

(in millions)202520242023
Interest income$3 $3 $2 
Operating, interest and other expenses389 342 299 
Loss before equity in earnings of subsidiaries(386)(339)(297)
Equity in earnings of subsidiaries4,835 1,610 1,498 
Income before income taxes4,449 1,271 1,201 
Income tax benefit(108)(100)(83)
Net income4,557 1,371 1,284 
Preferred stock dividend requirements of Edison International98 87 87 
Net income available to Edison International common shareholders$4,459 $1,284 $1,197 
153
Table of Contents
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
For the Years Ended December 31, 2025, 2024 and 2023

(in millions)202520242023
Net income$4,557 $1,371 $1,284 
Other comprehensive income, net of tax6 9 2 
Comprehensive income$4,563 $1,380 $1,286 
154
Table of Contents
EDISON INTERNATIONAL
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT
CONDENSED STATEMENTS OF CASH FLOWS
For the Years Ended December 31, 2025, 2024 and 2023

(in millions)202520242023
Net cash provided by operating activities$1,930 $1,097 $1,148 
Cash flows from financing activities:
Long-term debt issued544 1,049 1,549 
Long-term debt issuance costs(4)(7)(16)
Long-term debt repaid(800)(500)(400)
Short-term debt issued850 — 370 
Short-term debt repaid(101)(15)(1,356)
Common stock issued5 12 20 
Common stock repurchased(32)(200)—
Preferred stock repurchased(1,160)(28)(289)
Payable due to affiliates— — (3)
Commercial paper borrowing, net of repayments158 214 139 
Payments for stock-based compensation(21)(24)(5)
Receipts for stock-based compensation22 206 71 
Common stock dividends paid(1,274)(1,198)(1,112)
Preferred stock dividends paid(104)(88)(108)
Net cash used in financing activities(1,917)(579)(1,140)
Cash flows from investing activities:
Capital contributions to affiliate(16)(516)(15)
Dividends from affiliate— 1 4 
Net cash used in investing activities:(16)(515)(11)
Net (decrease) increase in cash and cash equivalents(3)3 (3)
Cash and cash equivalents, beginning of year4 1 4 
Cash and cash equivalents, end of year$1 $4 $1 
155
Table of Contents
Note 1. Basis of Presentation
The accompanying condensed financial statements of Edison International Parent should be read in conjunction with the consolidated financial statements and notes thereto of Edison International and subsidiaries ("Registrant") included in this Form 10-K. Edison International Parent's significant accounting policies are consistent with those of the Registrant, SCE and other wholly owned and controlled subsidiaries.
Dividends Received
Edison International Parent received cash dividends from SCE of $2.2 billion, $1.4 billion, and $1.4 billion in 2025, 2024, and 2023, respectively.
Dividend Restrictions
For information on Edison International Parent dividend restrictions, see "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—SCE Dividends" and "—Edison International Dividends."
Note 2. Debt and Equity Financing
Long-Term Debt
The following table summarizes Edison International Parent's long-term debt at December 31, 2025:
(in millions)
5.75% Senior Note due 2027
$600 
4.125% Senior Note due 2028
550 
5.25% Senior Note due 2028
600 
6.95% Senior Note due 2029
550 
5.45% Senior Note due 2029
500 
6.25% Senior Note due 2030
550 
5.25% Senior Note due 2032
550 
8.125% Junior Subordinated Note due 2053
500 
7.875% Junior Subordinated Note due 2054
450 
For information on Edison International Parent's material provisions on long-term debt and credit facility, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements—Liens and Security Interests" and "—Credit Agreements and Short-Term Debt."
Common and Preferred Stock
For information on Edison International Parent common stock and preferred stock, see "Notes to Consolidated Financial Statements—Note 14. Equity."
Note 3. Related-Party Transactions
Edison International's Parent expense from services provided by SCE was $2 million for the years ended December 31, 2025, 2024 and 2023. Edison International Parent's interest expense from loans due to affiliates was $2 million for the years ended December 31, 2025, 2024 and 2023. Edison International Parent had current related-party receivables of $565 million and $571 million and current related-party payables of $229 million and $186 million at December 31, 2025 and 2024, respectively. Edison International Parent had long-term related-party payables of $113 million and $98 million at December 31, 2025 and 2024, respectively. For a discussion of Edison International Parent's contribution to Edison International Foundation for the years ended December 31, 2025, 2024 and 2023 see "Notes to Consolidated Financial Statements—Note 17. Related Party Transactions."
Note 4. Contingencies
For a discussion of material contingencies see "Notes to Consolidated Financial Statements—Note 8. Income Taxes" and "—Note 12. Commitments and Contingencies."
156
Table of Contents
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized.
EDISON INTERNATIONALSOUTHERN CALIFORNIA EDISON COMPANY
By:/s/ Kara G. RyanBy:/s/ Kara G. Ryan
Kara G. Ryan
Vice President, Chief Accounting Officer and Controller
(Duly Authorized Officer and
Principal Accounting Officer)
Kara G. Ryan
Vice President, Chief Accounting Officer and Controller
(Duly Authorized Officer and
Principal Accounting Officer)
Date:February 18, 2026Date:February 18, 2026
157
Table of Contents
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrants and in the capacities and on the date indicated.
SignatureTitle
A. Principal Executive Officers
Pedro J. Pizarro*
President, Chief Executive Officer and Director
(Edison International)
Steven D. Powell*
President and Chief Executive Officer and Director
(Southern California Edison Company)
B. Principal Financial Officers
Maria Rigatti*
Executive Vice President and Chief Financial Officer
(Edison International)
Aaron D. Moss*
Senior Vice President and Chief Financial Officer
(Southern California Edison Company)
C. Principal Accounting Officers
/s/ Kara G. Ryan
Vice President, Chief Accounting Officer and Controller
(Edison International)
Kara G. Ryan
/s/ Kara G. Ryan
Vice President, Chief Accounting Officer and Controller
(Southern California Edison Company)
Kara G. Ryan
D. Directors (Edison International and Southern California Edison Company, unless otherwise noted)
Jeanne Beliveau-Dunn*Director
Michael C. Camuñez*Director
Jennifer M. Granholm*Director
James T. Morris*Director
Timothy T. O'Toole*Director
Pedro J. Pizarro*Director
Steven D. Powell (SCE only)*Director
Marcy L. Reed*Director
Carey A. Smith*Director
Linda G. Stuntz*Director
Peter J. Taylor*Chair of the Edison International Board and Director
Keith Trent*Director
*By:/s/ Kara G. Ryan*By:/s/ Kara G. Ryan
Kara G. Ryan
Vice President, Chief Accounting Officer and Controller
(Attorney-in-fact for EIX Directors and Officers)
Kara G. Ryan
Vice President, Chief Accounting Officer and Controller
(Attorney-in-fact for SCE Directors and Officers)
Date:February 18, 2026Date:February 18, 2026
158

What is the market capitalization of a company?

The market capitalization sometimes referred as Marketcap, is the value of a publicly listed company.
In most cases it can be easily calculated by multiplying the share price with the amount of outstanding shares.

DISCLAIMER

CompaniesMarketCap is not associated in any way with CoinMarketCap.com
Stock prices are delayed, the delay can range from a few minutes to several hours.
Company logos are from the CompaniesLogo.com logo database and belong to their respective copyright holders. Companies Marketcap displays them for editorial purposes only.

Contact

For inquiries or if you want to report a problem write to hello@8marketcap.com

Links

- Privacy policy

- Terms and conditions

© 2025 CompaniesMarketcap.com