000006675612/313,349,606,30057,252,8642022FYfalse——80.080.057.253.257.253.20.20.10.10.13.03.1P4Ythreeno5055555511111234http://fasb.org/us-gaap/2022#OtherLiabilitiesCurrenthttp://fasb.org/us-gaap/2022#OtherLiabilitiesCurrenthttp://fasb.org/us-gaap/2022#OtherLiabilitiesNoncurrenthttp://fasb.org/us-gaap/2022#OtherLiabilitiesNoncurrenthttp://fasb.org/us-gaap/2022#OtherAssetsNoncurrenthttp://fasb.org/us-gaap/2022#OtherAssetsNoncurrent513550350507518709.314.79.314.7.0420.50nono4.853.023.406.023.694.905.103.205.993.304.083.742.503.862.794.545.696.005.824.084.214.955.054.394.074.473.303.113.262.654.15SOFR0.754.144.94252501332501001002528nonenonenonononononothree yearsthree yearsthree yearsthree yearsthree yearsthree yearstwo00000667562022-01-012022-12-3100000667562022-06-30iso4217:USD00000667562023-02-01xbrli:shares0000066756ale:BniCoalReclamationLiabilityMember2022-12-310000066756ale:MinnesotaPowerMemberale:SolarGenerationMember2022-12-31utr:MW0000066756ale:SolarGenerationMemberale:CorporateOtherOtherMember2022-12-3100000667562022-12-3100000667562021-12-31iso4217:USDxbrli:shares00000667562021-01-012021-12-3100000667562020-01-012020-12-3100000667562020-12-3100000667562019-12-310000066756us-gaap:CommonStockMember2021-12-310000066756us-gaap:CommonStockMember2020-12-310000066756us-gaap:CommonStockMember2019-12-310000066756us-gaap:CommonStockMember2022-01-012022-12-310000066756us-gaap:CommonStockMember2021-01-012021-12-310000066756us-gaap:CommonStockMember2020-01-012020-12-310000066756us-gaap:CommonStockMember2022-12-310000066756us-gaap:AccumulatedOtherComprehensiveIncomeMember2021-12-310000066756us-gaap:AccumulatedOtherComprehensiveIncomeMember2020-12-310000066756us-gaap:AccumulatedOtherComprehensiveIncomeMember2019-12-310000066756us-gaap:AccumulatedOtherComprehensiveIncomeMember2022-01-012022-12-310000066756us-gaap:AccumulatedOtherComprehensiveIncomeMember2021-01-012021-12-310000066756us-gaap:AccumulatedOtherComprehensiveIncomeMember2020-01-012020-12-310000066756us-gaap:AccumulatedOtherComprehensiveIncomeMember2022-12-310000066756us-gaap:RetainedEarningsMember2021-12-310000066756us-gaap:RetainedEarningsMember2020-12-310000066756us-gaap:RetainedEarningsMember2019-12-310000066756us-gaap:RetainedEarningsMember2022-01-012022-12-310000066756us-gaap:RetainedEarningsMember2021-01-012021-12-310000066756us-gaap:RetainedEarningsMember2020-01-012020-12-310000066756us-gaap:RetainedEarningsMember2022-12-310000066756us-gaap:NoncontrollingInterestMember2021-12-310000066756us-gaap:NoncontrollingInterestMember2020-12-310000066756us-gaap:NoncontrollingInterestMember2019-12-310000066756us-gaap:NoncontrollingInterestMember2022-01-012022-12-310000066756us-gaap:NoncontrollingInterestMember2021-01-012021-12-310000066756us-gaap:NoncontrollingInterestMember2020-01-012020-12-310000066756us-gaap:NoncontrollingInterestMember2022-12-31xbrli:pure0000066756ale:RegulatedOperationsMemberMemberus-gaap:RetailMemberale:ElectricRatesMemberale:MinnesotaPowerMember2022-12-31ale:Customers0000066756ale:RegulatedOperationsMemberMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:MunicipalCustomersMember2022-12-310000066756ale:RegulatedOperationsMemberMemberale:SWLPMemberus-gaap:RetailMemberale:ElectricRatesMember2022-12-310000066756ale:RegulatedOperationsMemberMemberale:NaturalGasMemberale:SWLPMemberus-gaap:RetailMember2022-12-310000066756ale:RegulatedOperationsMemberMemberale:SWLPMemberus-gaap:RetailMemberale:WaterMember2022-12-310000066756ale:ALLETECleanEnergyMemberale:ALLETECleanEnergyMember2022-12-310000066756ale:Nobles2Member2022-12-310000066756ale:TenaskaMemberale:MinnesotaPowerMemberale:WindTurbineGeneratorsMemberale:TenaskaPPAMember2022-12-310000066756ale:TenaskaMemberale:MinnesotaPowerMemberale:WindTurbineGeneratorsMemberale:TenaskaPPAMember2022-01-012022-12-310000066756ale:NemadjiTrailEnergyCenterMemberus-gaap:NaturalGasProcessingPlantMember2022-12-310000066756ale:NemadjiTrailEnergyCenterMemberale:SouthShoreEnergyMemberus-gaap:NaturalGasProcessingPlantMember2022-01-012022-12-310000066756ale:NemadjiTrailEnergyCenterMember2022-12-310000066756ale:NemadjiTrailEnergyCenterMemberale:SouthShoreEnergyMember2022-12-310000066756us-gaap:CorporateAndOtherMemberale:BNIEnergyMember2022-12-310000066756us-gaap:CorporateAndOtherMemberale:SquareButteCoalFiredUnitMemberale:BNIEnergyMember2022-12-310000066756ale:SquareButtePpaMemberale:SquareButteMemberale:MinnesotaPowerMemberale:SquareButteCoalFiredUnitMember2022-01-012022-12-310000066756ale:SquareButtePpaMemberale:SquareButteCoalFiredUnitMember2022-01-012022-12-310000066756us-gaap:CustomerConcentrationRiskMemberale:LargePowerCustomerMember2022-12-310000066756us-gaap:CustomerConcentrationRiskMemberale:LargePowerCustomerMember2021-12-310000066756us-gaap:CustomerConcentrationRiskMemberus-gaap:SalesRevenueNetMemberale:RegulatedOperationsMemberale:LargestCustomerMemberale:LargePowerCustomerMember2022-01-012022-12-310000066756us-gaap:CustomerConcentrationRiskMemberus-gaap:SalesRevenueNetMemberale:LargestCustomerMemberale:LargePowerCustomerMember2022-01-012022-12-310000066756us-gaap:CustomerConcentrationRiskMemberus-gaap:SalesRevenueNetMemberale:RegulatedOperationsMemberale:LargestCustomerMemberale:LargePowerCustomerMember2021-01-012021-12-310000066756us-gaap:CustomerConcentrationRiskMemberus-gaap:SalesRevenueNetMemberale:LargestCustomerMemberale:LargePowerCustomerMember2021-01-012021-12-310000066756us-gaap:CustomerConcentrationRiskMemberus-gaap:SalesRevenueNetMemberale:RegulatedOperationsMemberale:LargestCustomerMemberale:LargePowerCustomerMember2020-01-012020-12-310000066756us-gaap:CustomerConcentrationRiskMemberus-gaap:SalesRevenueNetMemberale:LargestCustomerMemberale:LargePowerCustomerMember2020-01-012020-12-310000066756ale:BoswellUnit3Memberale:MPUCMemberale:A2021IntegratedResourcePlanMember2022-12-310000066756ale:MPUCMemberale:A2021IntegratedResourcePlanMemberale:BoswellUnit4Member2022-12-310000066756ale:MPUCMemberale:TaconiteHarborMemberale:ResourcePackageMember2022-12-310000066756srt:ScenarioPreviouslyReportedMember2020-01-012020-12-310000066756srt:RevisionOfPriorPeriodErrorCorrectionAdjustmentMember2020-01-012020-12-310000066756ale:RevisionOfPriorPeriodAdjustedBalanceMember2020-01-012020-12-310000066756srt:ScenarioPreviouslyReportedMember2021-12-310000066756srt:RevisionOfPriorPeriodErrorCorrectionAdjustmentMember2021-12-310000066756ale:RevisionOfPriorPeriodAdjustedBalanceMember2021-12-310000066756ale:NewEnergyMember2022-12-310000066756ale:BNIEnergyMember2022-12-310000066756ale:BNIEnergyMember2021-12-310000066756ale:VehiclesandEquipmentMember2022-12-310000066756ale:VehiclesandEquipmentMember2021-12-310000066756ale:LandandOtherMember2022-12-310000066756ale:LandandOtherMember2021-12-310000066756ale:MunicipalCustomersMemberus-gaap:LongTermContractWithCustomerMemberale:RegulatedOperationsMemberale:MunicipalMemberale:WholesaleElectricServiceMember2022-12-310000066756ale:IndustrialMemberale:RegulatedOperationsMemberale:RetailElectricServiceMemberale:IndustrialCustomersMember2022-01-012022-12-310000066756ale:IndustrialMemberus-gaap:LongTermContractWithCustomerMemberale:RegulatedOperationsMemberale:IndustrialCustomersMemberale:RetailElectricServiceMember2022-12-310000066756ale:IndustrialMember2023-01-01us-gaap:LongTermContractWithCustomerMemberale:RegulatedOperationsMemberale:IndustrialCustomersMember2022-12-3100000667562027-01-01ale:IndustrialMemberus-gaap:LongTermContractWithCustomerMemberale:RegulatedOperationsMemberale:IndustrialCustomersMember2022-12-310000066756ale:IndustrialMemberus-gaap:LongTermContractWithCustomerMemberale:RegulatedOperationsMemberale:IndustrialCustomersMember2028-01-012022-12-310000066756ale:SaleofEnergyunderPSAMemberale:OtherPowerSupplierCustomersMemberus-gaap:LongTermContractWithCustomerMemberale:RegulatedOperationsMemberale:OtherPowerSuppliersMember2022-12-310000066756ale:RegulatedOperationsMemberale:AlternativeProgramsMember2022-01-012022-12-310000066756ale:GlenUllinEnergyCenterMember2022-01-012022-12-310000066756ale:SouthPeakMember2022-01-012022-12-310000066756ale:DiamondSpringMember2022-01-012022-12-310000066756ale:CaddoMember2022-01-012022-12-310000066756ale:Nobles2Member2022-01-012022-12-310000066756ale:PensionandOtherPostretirementBenefitPlansNonServiceCreditMember2022-01-012022-12-310000066756ale:PensionandOtherPostretirementBenefitPlansNonServiceCreditMember2021-01-012021-12-310000066756ale:PensionandOtherPostretirementBenefitPlansNonServiceCreditMember2020-01-012020-12-310000066756ale:InterestandInvestmentEarningsMember2022-01-012022-12-310000066756ale:InterestandInvestmentEarningsMember2021-01-012021-12-310000066756ale:InterestandInvestmentEarningsMember2020-01-012020-12-310000066756ale:AFUDCEquityMember2022-01-012022-12-310000066756ale:AFUDCEquityMember2021-01-012021-12-310000066756ale:AFUDCEquityMember2020-01-012020-12-310000066756ale:GainLossonLandSalesMember2022-01-012022-12-310000066756ale:GainLossonLandSalesMember2021-01-012021-12-310000066756ale:GainLossonLandSalesMember2020-01-012020-12-310000066756ale:PSALiabilityMember2022-01-012022-12-310000066756ale:PSALiabilityMember2021-01-012021-12-310000066756ale:PSALiabilityMember2020-01-012020-12-310000066756ale:OtherIncomeExpenseOtherMember2022-01-012022-12-310000066756ale:OtherIncomeExpenseOtherMember2021-01-012021-12-310000066756ale:OtherIncomeExpenseOtherMember2020-01-012020-12-3100000667562024-01-01ale:IndustrialMemberus-gaap:LongTermContractWithCustomerMemberale:RegulatedOperationsMemberale:IndustrialCustomersMember2022-12-310000066756ale:IndustrialMemberus-gaap:LongTermContractWithCustomerMember2025-01-01ale:RegulatedOperationsMemberale:IndustrialCustomersMember2022-12-310000066756ale:IndustrialMemberus-gaap:LongTermContractWithCustomerMemberale:RegulatedOperationsMemberale:IndustrialCustomersMember2026-01-012022-12-310000066756us-gaap:LongTermContractWithCustomerMemberale:MunicipalMemberale:RegulatedOperationsMemberale:MunicipalCustomersMemberale:RetailElectricServiceMember2022-01-012022-12-310000066756ale:IndustrialMemberus-gaap:LongTermContractWithCustomerMemberale:RegulatedOperationsMemberale:IndustrialCustomersMemberale:RetailElectricServiceMember2022-01-012022-12-310000066756ale:RegulatedOperationsMemberMember2022-12-310000066756ale:RegulatedOperationsMemberMember2021-12-310000066756ale:ALLETECleanEnergyMember2022-12-310000066756ale:ALLETECleanEnergyMember2021-12-310000066756us-gaap:CorporateAndOtherMember2022-12-310000066756us-gaap:CorporateAndOtherMember2021-12-310000066756srt:MinimumMemberale:ALLETECleanEnergyMember2022-01-012022-12-310000066756ale:RegulatedOperationsMemberMembersrt:MinimumMemberus-gaap:ElectricityGenerationPlantNonNuclearMember2022-01-012022-12-310000066756ale:ALLETECleanEnergyMembersrt:MaximumMember2022-01-012022-12-310000066756ale:RegulatedOperationsMemberMemberus-gaap:ElectricityGenerationPlantNonNuclearMembersrt:MaximumMember2022-01-012022-12-310000066756srt:MinimumMemberus-gaap:CorporateAndOtherMember2022-01-012022-12-310000066756ale:RegulatedOperationsMemberMembersrt:MinimumMemberus-gaap:ElectricTransmissionMember2022-01-012022-12-310000066756us-gaap:CorporateAndOtherMembersrt:MaximumMember2022-01-012022-12-310000066756ale:RegulatedOperationsMemberMemberus-gaap:ElectricTransmissionMembersrt:MaximumMember2022-01-012022-12-310000066756ale:RegulatedOperationsMemberMembersrt:MinimumMemberus-gaap:ElectricDistributionMember2022-01-012022-12-310000066756ale:RegulatedOperationsMemberMemberus-gaap:ElectricDistributionMembersrt:MaximumMember2022-01-012022-12-310000066756ale:MinnesotaPowerMemberus-gaap:JointlyOwnedElectricityGenerationPlantMemberale:BoswellUnit4Member2022-12-310000066756us-gaap:JointlyOwnedElectricityGenerationPlantMemberale:BoswellUnit4Member2022-12-310000066756ale:WPPIEnergyMemberus-gaap:JointlyOwnedElectricityGenerationPlantMemberale:BoswellUnit4Member2022-12-310000066756us-gaap:JointlyOwnedElectricityTransmissionAndDistributionSystemMemberale:Capx2020Member2022-12-310000066756us-gaap:JointlyOwnedElectricityGenerationPlantMemberale:BoswellUnit4Member2021-12-310000066756us-gaap:JointlyOwnedElectricityTransmissionAndDistributionSystemMemberale:Capx2020Member2021-12-310000066756srt:MinimumMemberus-gaap:JointlyOwnedElectricityTransmissionAndDistributionSystemMemberale:Capx2020Member2022-12-310000066756srt:MaximumMemberus-gaap:JointlyOwnedElectricityTransmissionAndDistributionSystemMemberale:Capx2020Member2022-12-310000066756srt:MinimumMemberus-gaap:JointlyOwnedElectricityTransmissionAndDistributionSystemMemberale:Capx2020Member2021-12-310000066756srt:MaximumMemberus-gaap:JointlyOwnedElectricityTransmissionAndDistributionSystemMemberale:Capx2020Member2021-12-310000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:CurrentCostRecoveryRiderMember2022-01-012022-12-310000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:CurrentCostRecoveryRiderMember2021-01-012021-12-310000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:CurrentCostRecoveryRiderMember2020-01-012020-12-310000066756ale:MPUCMemberale:RetailCustomersMemberale:A2016MinnesotaGeneralRateReviewMemberale:ElectricRatesMemberale:MinnesotaPowerMember2020-01-012021-12-310000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:A2020MinnesotaGeneralRateReviewMember2019-11-012019-11-010000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:A2020MinnesotaGeneralRateReviewMember2020-01-012020-04-300000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:A2020MinnesotaGeneralRateReviewMember2020-05-012020-12-310000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:A2020MinnesotaGeneralRateReviewMember2021-04-012021-06-300000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:A2022MinnesotaGeneralRateReviewMember2021-11-012021-11-010000066756ale:ResidentialMemberale:MPUCMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:A2022MinnesotaGeneralRateReviewMember2021-11-012021-11-010000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberus-gaap:SubsequentEventMemberale:A2022MinnesotaGeneralRateReviewMember2023-01-232023-01-230000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:A2022MinnesotaGeneralRateReviewMember2022-12-310000066756ale:MPUCMemberale:RetailCustomersMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:A2022MinnesotaGeneralRateReviewMember2022-01-012022-12-310000066756ale:FERCMemberale:FercApprovedWholesaleRatesMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:MunicipalCustomersMember2022-12-31ale:Years0000066756ale:FERCMemberale:FercApprovedWholesaleRatesMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:WholesaleElectricContractCostBasedFormulaMethodologyforEntireTermMemberale:MunicipalCustomersMember2022-12-310000066756ale:FERCMemberale:FercApprovedWholesaleRatesMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:WholesaleElectricContractsThrough2029Memberale:MunicipalCustomersMember2022-12-310000066756ale:CostRecoveryRidersMemberale:MPUCMemberale:ElectricRatesMemberale:MinnesotaPowerMember2022-12-310000066756ale:MPUCMemberale:ElectricRatesMemberale:MinnesotaPowerMemberale:FuelAdjustmentClauseMember2021-12-310000066756ale:FuelAdjustmentClause2022Memberale:MPUCMemberale:ElectricRatesMemberale:MinnesotaPowerMember2022-12-310000066756ale:MPUCMemberale:FuelAdjustmentClauseFilingMemberale:MinnesotaPowerMember2018-07-012019-12-310000066756ale:MPUCMemberale:FuelAdjustmentClauseFilingMemberale:MinnesotaPowerMember2021-08-110000066756ale:MPUCMemberale:FuelAdjustmentClauseFilingMemberale:MinnesotaPowerMember2022-01-132022-01-130000066756ale:SWLPMemberale:RetailCustomersMemberale:A2018WisconsinGeneralRateCaseMemberale:PSCWMember2020-01-012022-12-310000066756ale:SWLPMemberale:RetailCustomersMemberale:PSCWMemberale:A2022WisconsinGeneralRateReviewMember2022-06-012022-06-010000066756ale:SWLPMemberale:RetailCustomersMemberale:PSCWMemberale:A2022WisconsinGeneralRateReviewMember2022-12-202022-12-200000066756ale:A2022WisconsinGeneralRateCaseMemberale:SWLPMemberale:RetailCustomersMemberale:PSCWMember2022-12-202022-12-200000066756ale:RenewableGenerationMemberale:MPUCMemberale:A2021IntegratedResourcePlanMembersrt:MaximumMember2021-02-010000066756ale:MPUCMembersrt:MinimumMember2022-12-310000066756ale:MPUCMemberale:MinnesotaPowerMemberale:CIPConsolidatedFilingMemberMember2022-01-012022-12-310000066756ale:MPUCMemberale:MinnesotaPowerMemberale:CIPConsolidatedFilingMember2021-01-012021-12-310000066756ale:MPUCMemberale:MinnesotaPowerMemberale:CIPConsolidatedFilingMember2020-01-012020-12-310000066756ale:FERCMember2022-12-310000066756ale:MPUCMember2022-12-310000066756ale:FuelAdjustmentClauseMember2022-12-310000066756ale:FuelAdjustmentClauseMember2021-12-310000066756us-gaap:PensionAndOtherPostretirementPlansCostsMember2022-12-310000066756us-gaap:PensionAndOtherPostretirementPlansCostsMember2021-12-310000066756us-gaap:DeferredIncomeTaxChargesMember2022-12-310000066756us-gaap:DeferredIncomeTaxChargesMember2021-12-310000066756us-gaap:RegulatoryClauseRevenuesUnderRecoveredMember2022-12-310000066756us-gaap:RegulatoryClauseRevenuesUnderRecoveredMember2021-12-310000066756us-gaap:AssetRetirementObligationCostsMember2022-12-310000066756us-gaap:AssetRetirementObligationCostsMember2021-12-310000066756ale:ManufacturedGasPlantMember2022-12-310000066756ale:ManufacturedGasPlantMember2021-12-310000066756ale:MedicarePartDRegulatoryAssetMember2022-12-310000066756ale:MedicarePartDRegulatoryAssetMember2021-12-310000066756us-gaap:OtherRegulatoryAssetsLiabilitiesMember2022-12-310000066756us-gaap:OtherRegulatoryAssetsLiabilitiesMember2021-12-310000066756ale:FuelAdjustmentClauseMember2022-12-310000066756ale:FuelAdjustmentClauseMember2021-12-310000066756ale:TransmissionFormulaRatesMember2022-12-310000066756ale:TransmissionFormulaRatesMember2021-12-310000066756us-gaap:OtherRegulatoryAssetsLiabilitiesMember2022-12-310000066756us-gaap:OtherRegulatoryAssetsLiabilitiesMember2021-12-310000066756us-gaap:DeferredIncomeTaxChargesMember2022-12-310000066756us-gaap:DeferredIncomeTaxChargesMember2021-12-310000066756ale:WholesaleAndRetailContraAfudcMember2022-12-310000066756ale:WholesaleAndRetailContraAfudcMember2021-12-310000066756us-gaap:RemovalCostsMember2022-12-310000066756us-gaap:RemovalCostsMember2021-12-310000066756us-gaap:PensionAndOtherPostretirementPlansCostsMember2022-12-310000066756us-gaap:PensionAndOtherPostretirementPlansCostsMember2021-12-310000066756ale:NorthDakotaInvestmentTaxCreditsSubjecttoRefundMember2022-12-310000066756ale:NorthDakotaInvestmentTaxCreditsSubjecttoRefundMember2021-12-310000066756ale:Boswell12Member2022-12-310000066756ale:Boswell12Member2021-12-310000066756ale:NonJurisdictionalLandSalesMember2022-12-310000066756ale:NonJurisdictionalLandSalesMember2021-12-310000066756ale:MPUCMembersrt:MaximumMember2022-12-310000066756us-gaap:RegulatoryClauseRevenuesUnderRecoveredMember2022-01-012022-12-310000066756ale:NewEnergyMember2022-04-150000066756ale:NewEnergyMember2022-04-152022-04-150000066756ale:NewEnergyMember2022-01-012022-12-3100000667562022-04-152022-04-150000066756ale:ATCMember2022-12-310000066756us-gaap:SubsequentEventMemberale:ATCMember2023-01-312023-01-310000066756ale:ATCMember2022-01-012022-12-310000066756ale:ATCMember2021-12-310000066756ale:ATCMember2020-12-310000066756ale:ATCMember2021-01-012021-12-310000066756ale:ATCMember2022-12-310000066756ale:ATCMember2021-12-310000066756ale:ATCMember2022-01-012022-12-310000066756ale:ATCMember2021-01-012021-12-310000066756ale:ATCMember2020-01-012020-12-310000066756ale:ATCMember2020-01-012020-12-310000066756ale:Nobles2Member2022-01-012022-12-310000066756ale:Nobles2Member2021-12-310000066756ale:Nobles2Member2022-01-012022-12-310000066756us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2022-12-310000066756us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2022-12-310000066756us-gaap:FairValueMeasurementsRecurringMember2022-12-310000066756us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756us-gaap:FairValueMeasurementsRecurringMemberus-gaap:FairValueInputsLevel3Member2021-12-310000066756us-gaap:FairValueMeasurementsRecurringMember2021-12-310000066756us-gaap:FairValueMeasurementsRecurringMember2022-01-012022-12-310000066756us-gaap:FairValueInputsLevel2Member2022-12-310000066756us-gaap:FairValueInputsLevel2Member2021-12-310000066756ale:RegulatedOperationsMemberMemberus-gaap:FairValueMeasurementsNonrecurringMemberale:ATCMember2022-01-012022-12-310000066756us-gaap:FairValueMeasurementsNonrecurringMemberus-gaap:CorporateAndOtherMember2022-01-012022-12-310000066756us-gaap:FairValueMeasurementsRecurringMember2021-01-012021-12-310000066756ale:RegulatedOperationsMemberMemberus-gaap:FairValueMeasurementsNonrecurringMemberale:ATCMember2021-01-012021-12-310000066756us-gaap:RevolvingCreditFacilityMember2022-12-310000066756us-gaap:RevolvingCreditFacilityMember2021-12-310000066756ale:CampRipleyFinancingMember2022-01-012022-12-310000066756ale:CampRipleyFinancingMember2022-12-310000066756ale:FebruaryUnsecuredTermLoanTerminatedInApril2022Member2022-02-282022-02-280000066756ale:MarchUnsecuredTermLoanDueIn2023Member2022-01-012022-12-310000066756ale:ALLETEBonds454DueAugust2032Member2022-08-092022-08-090000066756ale:ALLETEBonds454DueAugust2032Member2022-08-090000066756ale:ALLETEBonds3.40DueJuly2022Member2022-12-310000066756ale:ALLETEBonds3.40DueJuly2022Member2021-12-310000066756ale:A602SeriesDue2023Member2022-12-310000066756ale:A602SeriesDue2023Member2021-12-310000066756ale:ALLETEBonds3.69DueMarch2024Member2022-12-310000066756ale:ALLETEBonds3.69DueMarch2024Member2021-12-310000066756ale:A490SeriesDue2025Member2022-12-310000066756ale:A490SeriesDue2025Member2021-12-310000066756ale:A510SeriesDue2025Member2022-12-310000066756ale:A510SeriesDue2025Member2021-12-310000066756ale:AlleteBonds320DueJuly2026Member2022-12-310000066756ale:AlleteBonds320DueJuly2026Member2021-12-310000066756ale:A599SeriesDue2027Member2022-12-310000066756ale:A599SeriesDue2027Member2021-12-310000066756ale:AlleteBonds330DueOctober2028Member2022-12-310000066756ale:AlleteBonds330DueOctober2028Member2021-12-310000066756ale:ALLETEBonds4.08DueMarch2029Member2022-12-310000066756ale:ALLETEBonds4.08DueMarch2029Member2021-12-310000066756ale:ALLETEBonds3.74DueSeptember2029Member2022-12-310000066756ale:ALLETEBonds3.74DueSeptember2029Member2021-12-310000066756ale:ALLETEBonds250DueAugust2030Member2022-12-310000066756ale:ALLETEBonds250DueAugust2030Member2021-12-310000066756ale:ALLETEBonds3.86DueSeptember2030Member2022-12-310000066756ale:ALLETEBonds3.86DueSeptember2030Member2021-12-310000066756ale:A279SeriesDue2031Member2022-12-310000066756ale:A279SeriesDue2031Member2021-12-310000066756ale:A454SeriesDue2032Member2022-12-310000066756ale:A454SeriesDue2032Member2021-12-310000066756ale:A569SeriesDue2036Member2022-12-310000066756ale:A569SeriesDue2036Member2021-12-310000066756ale:A600SeriesDue2040Member2022-12-310000066756ale:A600SeriesDue2040Member2021-12-310000066756ale:A582SeriesDue2040Member2022-12-310000066756ale:A582SeriesDue2040Member2021-12-310000066756ale:AlleteBonds408DueJuly2042Member2022-12-310000066756ale:AlleteBonds408DueJuly2042Member2021-12-310000066756ale:AlleteBonds421DueOctober2043Member2022-12-310000066756ale:AlleteBonds421DueOctober2043Member2021-12-310000066756ale:ALLETEBonds4.95DueMarch2044Member2022-12-310000066756ale:ALLETEBonds4.95DueMarch2044Member2021-12-310000066756ale:ALLETEBonds5.05DueJuly2044Member2022-12-310000066756ale:ALLETEBonds5.05DueJuly2044Member2021-12-310000066756ale:ALLETEBonds4.39DueSeptember2044Member2022-12-310000066756ale:ALLETEBonds4.39DueSeptember2044Member2021-12-310000066756ale:ALLETEBonds4.07DueApril2048Member2022-12-310000066756ale:ALLETEBonds4.07DueApril2048Member2021-12-310000066756ale:ALLETEBonds4.47DueMarch2049Member2022-12-310000066756ale:ALLETEBonds4.47DueMarch2049Member2021-12-310000066756ale:ALLETEBonds330DueAugust2050Member2022-12-310000066756ale:ALLETEBonds330DueAugust2050Member2021-12-310000066756ale:ArmeniaMountainSeniorSecuredNotes3.26Due2024Member2022-12-310000066756ale:ArmeniaMountainSeniorSecuredNotes3.26Due2024Member2021-12-310000066756ale:IndustrialDevelopmentVariableRateDemandRefundingRevenueBondsSeries2006Due2025Member2022-12-310000066756ale:IndustrialDevelopmentVariableRateDemandRefundingRevenueBondsSeries2006Due2025Member2021-12-310000066756ale:RevolvingCreditFacilityVariableRateDue2025Member2022-12-310000066756ale:RevolvingCreditFacilityVariableRateDue2025Member2021-12-310000066756ale:UnsecuredSeniorNotes265Due2025Member2022-12-310000066756ale:UnsecuredSeniorNotes265Due2025Member2021-12-310000066756ale:ALLETESeniorUnsecuredNotes3.11Due2027Member2022-12-310000066756ale:ALLETESeniorUnsecuredNotes3.11Due2027Member2021-12-310000066756ale:SWLPFirstMortgageBonds4.15SeriesDue2028Member2022-12-310000066756ale:SWLPFirstMortgageBonds4.15SeriesDue2028Member2021-12-310000066756ale:SWLPFirstMortgageBonds4.14SeriesDue2048Member2022-12-310000066756ale:SWLPFirstMortgageBonds4.14SeriesDue2048Member2021-12-310000066756ale:UnsecuredTermLoanVariableRateDue2022Member2022-12-310000066756ale:UnsecuredTermLoanVariableRateDue2022Member2021-12-310000066756ale:UnsecuredTermLoanVariableRateDue2023Member2022-12-310000066756ale:UnsecuredTermLoanVariableRateDue2023Member2021-12-310000066756ale:OtherLongTermDebtMember2022-12-310000066756ale:OtherLongTermDebtMember2021-12-310000066756srt:MaximumMember2022-12-310000066756ale:A485SeriesDue2021Member2022-12-310000066756ale:ALLETEBonds3.02DueSeptember2021Member2022-12-310000066756srt:WeightedAverageMemberale:OtherLongTermDebtMember2022-12-310000066756us-gaap:CapitalAdditionsMember2022-12-310000066756ale:EasementsMember2022-12-310000066756ale:PowerPurchaseAgreementMember2022-12-310000066756ale:OtherPurchaseObligationsMember2022-12-310000066756ale:SquareButtePpaMemberale:SquareButteMemberale:SquareButteCoalFiredUnitMember2022-12-310000066756ale:SquareButtePpaMemberale:SquareButteMember2022-01-012022-12-310000066756ale:SquareButtePpaMemberale:SquareButteMemberale:MinnesotaPowerMemberale:SquareButteCoalFiredUnitMemberale:A20230101Member2022-01-012022-12-310000066756ale:SquareButtePpaMemberale:SquareButteMemberale:MinnesotaPowerMemberale:SquareButteCoalFiredUnitMemberale:A20240101Member2022-01-012022-12-310000066756ale:SquareButtePpaMemberale:SquareButteMemberale:MinnesotaPowerMemberale:SquareButteCoalFiredUnitMemberale:A20250101Member2022-01-012022-12-310000066756ale:SquareButtePpaMemberale:SquareButteMemberale:MinnesotaPowerMemberale:SquareButteCoalFiredUnitMemberale:A20260101Member2022-01-012022-12-310000066756ale:SquareButtePpaMemberale:SquareButteMemberale:MinnesotaPowerMember2022-01-012022-12-310000066756ale:SquareButtePpaMemberale:SquareButteMemberale:MinnesotaPowerMember2021-01-012021-12-310000066756ale:SquareButtePpaMemberale:SquareButteMemberale:MinnesotaPowerMember2020-01-012020-12-310000066756ale:OliverWindMemberale:MinnesotaPowerMemberale:OliverWindIPpaMember2022-12-310000066756ale:OliverWindMemberale:MinnesotaPowerMemberale:OliverWindIiPpaMember2022-12-310000066756ale:BasinElectricCooperativePSAJune2022May2023Memberale:MinnesotaPowerMemberale:BasinElectricPowerCooperativeMember2022-12-310000066756ale:MinnesotaPowerMemberale:BasinElectricPowerCooperativeMemberale:BasinElectricCooperativePSAJune2023May2025Member2022-12-310000066756ale:MinnkotaSalesAgreementMemberale:SquareButtePpaMemberale:MinnkotaPowerMemberale:SquareButteCoalFiredUnitMember2022-01-012022-12-310000066756ale:MinnkotaSalesAgreementMemberale:SquareButtePpaMemberale:MinnkotaPowerMemberale:SquareButteCoalFiredUnitMember2021-01-012021-12-310000066756ale:MinnesotaPowerMemberale:SilverBayPowerMemberale:SilverBayPowerCoalLiquidandGaseousFuelsfiredUnitsMember2022-12-310000066756ale:CalpineCorporationMemberale:MinnesotaPowerMemberale:CalpineCorporationPPAMember2022-12-310000066756ale:ManitobaHydroPpaExpires2035Memberale:MinnesotaPowerMemberale:ManitobaHydroMember2022-12-310000066756ale:ManitobaHydroPPAexpires2040Memberale:MinnesotaPowerMemberale:ManitobaHydroMember2022-12-310000066756ale:Nobles2Memberale:TenaskaMemberale:MinnesotaPowerMember2022-12-310000066756ale:BasinMemberale:MinnesotaPowerMemberale:BasinPowerSalesAgreementexpiresMay2028Member2022-12-310000066756ale:GreatRiverEnergyMemberale:MinnesotaPowerMemberale:GreatRiverEnergyPowerSalesAgreementExpiresMay2025Member2022-12-310000066756ale:OcontoElectricCooperativePowerSalesAgreementMemberale:MinnesotaPowerMemberale:OcontoElectricCooperativeMember2022-12-310000066756ale:MinnkotaSalesAgreementMemberale:SquareButtePpaMemberale:MinnkotaPowerMemberale:SquareButteCoalFiredUnitMember2020-01-012020-12-310000066756ale:CoalCombustionResidualsMemberale:MinnesotaPowerMember2022-01-012022-12-310000066756ale:CoalCombustionResidualsMembersrt:MinimumMemberale:MinnesotaPowerMember2022-01-012022-12-310000066756ale:CoalCombustionResidualsMemberale:MinnesotaPowerMembersrt:MaximumMember2022-01-012022-12-310000066756ale:SWLPMemberale:SuperiorWIMemberale:ManufacturedGasPlantMember2022-12-310000066756us-gaap:FinancialStandbyLetterOfCreditMemberale:AlleteIncMember2022-12-310000066756us-gaap:FinancialStandbyLetterOfCreditMemberale:RegulatedOperationsMember2022-12-310000066756us-gaap:FinancialStandbyLetterOfCreditMemberale:ALLETECleanEnergyMember2022-12-310000066756ale:BniCoalReclamationLiabilityMemberus-gaap:SuretyBondMember2022-12-310000066756us-gaap:FinancialStandbyLetterOfCreditMemberale:ALLETESouthWindMember2022-12-310000066756ale:NewEnergyMemberus-gaap:FinancialStandbyLetterOfCreditMember2022-12-310000066756us-gaap:FinancialStandbyLetterOfCreditMemberale:SouthShoreEnergyMember2022-12-310000066756ale:SuretyBondsandLettersofCreditMemberale:AlletePropertiesPerformanceAndMaintenanceObligationsMember2022-12-310000066756ale:AlletePropertiesPerformanceAndMaintenanceObligationsMember2022-12-310000066756ale:TownCenterCommunityDevelopmentDistrictMember2022-12-310000066756ale:TownCenterCommunityDevelopmentDistrictMember2022-01-012022-12-310000066756ale:TownCenterCommunityDevelopmentDistrictMember2021-12-310000066756us-gaap:CommonStockMember2019-12-310000066756us-gaap:CommonStockMember2020-01-012020-12-310000066756us-gaap:CommonStockMember2020-12-310000066756us-gaap:CommonStockMember2021-01-012021-12-310000066756us-gaap:CommonStockMember2021-12-310000066756us-gaap:CommonStockMember2022-01-012022-12-310000066756us-gaap:CommonStockMember2022-12-310000066756us-gaap:CommonStockMemberale:PIESharesMember2022-01-012022-12-310000066756us-gaap:CommonStockMemberale:PIESharesMember2021-01-012021-12-310000066756us-gaap:CommonStockMemberale:PIESharesMember2020-01-012020-12-3100000667562022-04-052022-04-050000066756us-gaap:InternalRevenueServiceIRSMember2022-12-310000066756us-gaap:InternalRevenueServiceIRSMember2021-12-310000066756us-gaap:StateAndLocalJurisdictionMember2022-12-310000066756us-gaap:StateAndLocalJurisdictionMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMember2022-01-012022-12-310000066756us-gaap:PensionPlansDefinedBenefitMember2021-01-012021-12-310000066756us-gaap:PensionPlansDefinedBenefitMember2020-01-012020-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:VebaMember2022-01-012022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:VebaMember2021-01-012021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:VebaMember2020-01-012020-12-310000066756us-gaap:TrustForBenefitOfEmployeesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2022-01-012022-12-310000066756us-gaap:TrustForBenefitOfEmployeesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2021-01-012021-12-310000066756us-gaap:TrustForBenefitOfEmployeesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2020-01-012020-12-310000066756us-gaap:SubsequentEventMember2023-01-172023-01-170000066756us-gaap:PensionPlansDefinedBenefitMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMember2020-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2022-01-012022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2020-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2021-01-012021-12-310000066756us-gaap:TrustForBenefitOfEmployeesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2022-12-310000066756us-gaap:TrustForBenefitOfEmployeesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2020-01-012020-12-310000066756us-gaap:EquitySecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2022-12-310000066756us-gaap:EquitySecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2021-12-310000066756us-gaap:EquitySecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2022-12-310000066756us-gaap:EquitySecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2021-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2022-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMember2021-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2022-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2021-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:PensionPlansDefinedBenefitMember2022-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:PensionPlansDefinedBenefitMember2021-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2022-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:RealEstateMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:RealEstateMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:RealEstateMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:RealEstateMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Memberale:USLargeCapMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberale:USLargeCapMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:USLargeCapMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:USLargeCapMember2022-12-310000066756ale:USMidCapGrowthMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756ale:USMidCapGrowthMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2022-12-310000066756ale:USMidCapGrowthMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2022-12-310000066756ale:USMidCapGrowthMemberus-gaap:PensionPlansDefinedBenefitMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:USSmallCapMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:USSmallCapMemberus-gaap:FairValueInputsLevel2Member2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:USSmallCapMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:USSmallCapMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:InternationalMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:InternationalMemberus-gaap:FairValueInputsLevel2Member2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:InternationalMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:InternationalMember2022-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2022-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Memberus-gaap:CashAndCashEquivalentsMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberus-gaap:CashAndCashEquivalentsMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:CashAndCashEquivalentsMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:CashAndCashEquivalentsMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:RealEstateMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberus-gaap:RealEstateMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:RealEstateMember2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:RealEstateMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:RealEstateMember2022-01-012022-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Memberale:USLargeCapMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberale:USLargeCapMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:USLargeCapMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:USLargeCapMember2021-12-310000066756ale:USMidCapGrowthMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756ale:USMidCapGrowthMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756ale:USMidCapGrowthMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2021-12-310000066756ale:USMidCapGrowthMemberus-gaap:PensionPlansDefinedBenefitMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:USSmallCapMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:USSmallCapMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:USSmallCapMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:USSmallCapMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:InternationalMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:InternationalMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:InternationalMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberale:InternationalMember2021-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Memberus-gaap:CashAndCashEquivalentsMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberus-gaap:CashAndCashEquivalentsMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:CashAndCashEquivalentsMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:CashAndCashEquivalentsMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:RealEstateMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberus-gaap:RealEstateMember2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2021-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2020-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:RealEstateMember2020-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2021-01-012021-12-310000066756us-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:RealEstateMember2021-01-012021-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:PensionPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Memberale:USLargeCapMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberale:USLargeCapMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:USLargeCapMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:USLargeCapMember2022-12-310000066756ale:USMidCapGrowthMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756ale:USMidCapGrowthMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2022-12-310000066756ale:USMidCapGrowthMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2022-12-310000066756ale:USMidCapGrowthMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:USSmallCapMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:USSmallCapMemberus-gaap:FairValueInputsLevel2Member2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:USSmallCapMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:USSmallCapMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:InternationalMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:InternationalMemberus-gaap:FairValueInputsLevel2Member2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:InternationalMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:InternationalMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FixedIncomeFundsMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberus-gaap:FixedIncomeFundsMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:FixedIncomeFundsMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FixedIncomeFundsMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Memberus-gaap:CashAndCashEquivalentsMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberus-gaap:CashAndCashEquivalentsMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:CashAndCashEquivalentsMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:CashAndCashEquivalentsMember2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2022-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2021-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2022-01-012022-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2022-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Memberale:USLargeCapMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberale:USLargeCapMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:USLargeCapMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:USLargeCapMember2021-12-310000066756ale:USMidCapGrowthMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756ale:USMidCapGrowthMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756ale:USMidCapGrowthMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2021-12-310000066756ale:USMidCapGrowthMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:USSmallCapMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:USSmallCapMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:USSmallCapMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:USSmallCapMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:InternationalMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:InternationalMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberale:InternationalMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberale:InternationalMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FixedIncomeFundsMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberus-gaap:FixedIncomeFundsMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:FixedIncomeFundsMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FixedIncomeFundsMember2021-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756us-gaap:FixedIncomeSecuritiesMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Memberus-gaap:CashAndCashEquivalentsMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Memberus-gaap:CashAndCashEquivalentsMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Memberus-gaap:CashAndCashEquivalentsMember2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:CashAndCashEquivalentsMember2021-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel1Member2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel2Member2021-12-310000066756us-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2021-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2020-12-310000066756us-gaap:PrivateEquityFundsMemberus-gaap:OtherPostretirementBenefitPlansDefinedBenefitMemberus-gaap:FairValueInputsLevel3Member2021-01-012021-12-310000066756ale:ExecutivePlanMember2022-12-310000066756us-gaap:EmployeeStockMember2022-01-012022-12-310000066756us-gaap:PerformanceSharesMember2022-01-012022-12-310000066756us-gaap:PerformanceSharesMember2021-01-012021-12-310000066756us-gaap:PerformanceSharesMember2020-01-012020-12-310000066756us-gaap:RestrictedStockUnitsRSUMember2022-01-012022-12-310000066756us-gaap:RestrictedStockUnitsRSUMember2021-01-012021-12-310000066756us-gaap:RestrictedStockUnitsRSUMember2020-01-012020-12-310000066756us-gaap:PerformanceSharesMember2022-12-310000066756us-gaap:RestrictedStockUnitsRSUMember2022-12-310000066756us-gaap:PerformanceSharesMember2021-12-310000066756us-gaap:PerformanceSharesMember2020-12-310000066756us-gaap:PerformanceSharesMember2019-12-310000066756us-gaap:SubsequentEventMemberus-gaap:PerformanceSharesMember2023-02-012023-02-280000066756us-gaap:RestrictedStockUnitsRSUMember2021-12-310000066756us-gaap:RestrictedStockUnitsRSUMember2020-12-310000066756us-gaap:RestrictedStockUnitsRSUMember2019-12-310000066756us-gaap:SubsequentEventMemberus-gaap:RestrictedStockUnitsRSUMember2023-02-012023-02-280000066756ale:RegulatedOperationsMemberMember2022-01-012022-12-310000066756us-gaap:CorporateAndOtherMember2022-01-012022-12-310000066756ale:ResidentialMemberale:RegulatedOperationsMember2022-01-012022-12-310000066756ale:ResidentialMemberale:RegulatedOperationsMember2021-01-012021-12-310000066756ale:ResidentialMemberale:RegulatedOperationsMember2020-01-012020-12-310000066756ale:CommercialMemberale:RegulatedOperationsMember2022-01-012022-12-310000066756ale:CommercialMemberale:RegulatedOperationsMember2021-01-012021-12-310000066756ale:CommercialMemberale:RegulatedOperationsMember2020-01-012020-12-310000066756ale:RegulatedOperationsMemberale:MunicipalMember2022-01-012022-12-310000066756ale:RegulatedOperationsMemberale:MunicipalMember2021-01-012021-12-310000066756ale:RegulatedOperationsMemberale:MunicipalMember2020-01-012020-12-310000066756ale:IndustrialMemberale:RegulatedOperationsMember2022-01-012022-12-310000066756ale:IndustrialMemberale:RegulatedOperationsMember2021-01-012021-12-310000066756ale:IndustrialMemberale:RegulatedOperationsMember2020-01-012020-12-310000066756ale:RegulatedOperationsMemberale:OtherPowerSuppliersMember2022-01-012022-12-310000066756ale:RegulatedOperationsMemberale:OtherPowerSuppliersMember2021-01-012021-12-310000066756ale:RegulatedOperationsMemberale:OtherPowerSuppliersMember2020-01-012020-12-310000066756ale:RegulatedOperationsMemberale:OtherMember2022-01-012022-12-310000066756ale:RegulatedOperationsMemberale:OtherMember2021-01-012021-12-310000066756ale:RegulatedOperationsMemberale:OtherMember2020-01-012020-12-310000066756ale:RegulatedOperationsMember2022-01-012022-12-310000066756ale:RegulatedOperationsMember2021-01-012021-12-310000066756ale:RegulatedOperationsMember2020-01-012020-12-310000066756ale:LongtermPSAMemberale:ALLETECleanEnergyMember2022-01-012022-12-310000066756ale:LongtermPSAMemberale:ALLETECleanEnergyMember2021-01-012021-12-310000066756ale:LongtermPSAMemberale:ALLETECleanEnergyMember2020-01-012020-12-310000066756ale:SaleofWindEnergyFacilityMemberale:ALLETECleanEnergyMember2022-01-012022-12-310000066756ale:SaleofWindEnergyFacilityMemberale:ALLETECleanEnergyMember2021-01-012021-12-310000066756ale:SaleofWindEnergyFacilityMemberale:ALLETECleanEnergyMember2020-01-012020-12-310000066756ale:ALLETECleanEnergyOtherMemberale:ALLETECleanEnergyMember2022-01-012022-12-310000066756ale:ALLETECleanEnergyOtherMemberale:ALLETECleanEnergyMember2021-01-012021-12-310000066756ale:ALLETECleanEnergyOtherMemberale:ALLETECleanEnergyMember2020-01-012020-12-310000066756ale:ALLETECleanEnergyMember2022-01-012022-12-310000066756ale:ALLETECleanEnergyMember2021-01-012021-12-310000066756ale:ALLETECleanEnergyMember2020-01-012020-12-310000066756us-gaap:CorporateAndOtherMemberale:LongtermContractMember2022-01-012022-12-310000066756us-gaap:CorporateAndOtherMemberale:LongtermContractMember2021-01-012021-12-310000066756us-gaap:CorporateAndOtherMemberale:LongtermContractMember2020-01-012020-12-310000066756ale:SaleOfRenewableDevelopmentProjectsMemberus-gaap:CorporateAndOtherMember2022-01-012022-12-310000066756ale:SaleOfRenewableDevelopmentProjectsMemberus-gaap:CorporateAndOtherMember2021-01-012021-12-310000066756ale:SaleOfRenewableDevelopmentProjectsMemberus-gaap:CorporateAndOtherMember2020-01-012020-12-310000066756ale:CorporateOtherOtherMemberus-gaap:CorporateAndOtherMember2022-01-012022-12-310000066756ale:CorporateOtherOtherMemberus-gaap:CorporateAndOtherMember2021-01-012021-12-310000066756ale:CorporateOtherOtherMemberus-gaap:CorporateAndOtherMember2020-01-012020-12-310000066756us-gaap:CorporateAndOtherMember2021-01-012021-12-310000066756us-gaap:CorporateAndOtherMember2020-01-012020-12-310000066756us-gaap:CorporateAndOtherMemberale:NewEnergyMember2022-01-012022-12-310000066756ale:NemadjiTrailEnergyCenterMemberus-gaap:CorporateAndOtherMemberale:SouthShoreEnergyMember2021-01-012021-12-310000066756ale:RegulatedOperationsMemberMember2021-01-012021-12-310000066756ale:RegulatedOperationsMemberMember2020-01-012020-12-310000066756srt:ConsolidationEliminationsMember2022-01-012022-12-310000066756srt:ConsolidationEliminationsMember2021-01-012021-12-310000066756srt:ConsolidationEliminationsMember2020-01-012020-12-310000066756ale:RegulatedOperationsMember2022-12-310000066756ale:RegulatedOperationsMember2021-12-3100000667562022-01-012022-03-3100000667562022-04-012022-06-3000000667562022-07-012022-09-3000000667562022-10-012022-12-3100000667562021-01-012021-03-3100000667562021-04-012021-06-3000000667562021-07-012021-09-3000000667562021-10-012021-12-3100000667562020-01-012020-03-3100000667562020-04-012020-06-3000000667562020-07-012020-09-3000000667562020-10-012020-12-310000066756us-gaap:AllowanceForCreditLossMember2019-12-310000066756us-gaap:AllowanceForCreditLossMember2020-01-012020-12-310000066756us-gaap:AllowanceForCreditLossMember2020-12-310000066756us-gaap:AllowanceForLossesOnFinanceReceivablesMember2019-12-310000066756us-gaap:AllowanceForLossesOnFinanceReceivablesMember2020-01-012020-12-310000066756us-gaap:AllowanceForLossesOnFinanceReceivablesMember2020-12-310000066756us-gaap:AllowanceForCreditLossMember2021-01-012021-12-310000066756us-gaap:AllowanceForCreditLossMember2021-12-310000066756us-gaap:AllowanceForLossesOnFinanceReceivablesMember2021-01-012021-12-310000066756us-gaap:AllowanceForLossesOnFinanceReceivablesMember2021-12-310000066756us-gaap:AllowanceForCreditLossMember2022-01-012022-12-310000066756us-gaap:AllowanceForCreditLossMember2022-12-310000066756us-gaap:AllowanceForLossesOnFinanceReceivablesMember2022-01-012022-12-310000066756us-gaap:AllowanceForLossesOnFinanceReceivablesMember2022-12-310000066756us-gaap:ValuationAllowanceOfDeferredTaxAssetsMember2019-12-310000066756us-gaap:ValuationAllowanceOfDeferredTaxAssetsMember2020-01-012020-12-310000066756us-gaap:ValuationAllowanceOfDeferredTaxAssetsMember2020-12-310000066756us-gaap:ValuationAllowanceOfDeferredTaxAssetsMember2021-01-012021-12-310000066756us-gaap:ValuationAllowanceOfDeferredTaxAssetsMember2021-12-310000066756us-gaap:ValuationAllowanceOfDeferredTaxAssetsMember2022-01-012022-12-310000066756us-gaap:ValuationAllowanceOfDeferredTaxAssetsMember2022-12-31
Part I
Item 1. Business
Overview.
ALLETE is a leader in the nation’s clean-energy transformation. Our businesses and dedicated employees deliver sustainable energy solutions that mitigate climate change, build thriving communities, help customers reach their sustainability goals and drive value for shareholders. In 2020, ALLETE’s largest business, Minnesota Power, reached a milestone of providing 50 percent renewable energy to its retail and municipal customers in Minnesota, and the Company envisions delivering 100 percent carbon-free energy to customers by 2050—a vision grounded in a steadfast commitment to climate, customers and community through its EnergyForward strategy. ALLETE Clean Energy, our second-largest business, is positioned at the heart of society’s clean-energy transformation and owns, operates or is developing more than 1,300 megawatts of wind energy generation across eight states – helping some of the largest companies in the country reduce their carbon footprint.
Minnesota Power’s latest IRP, approved by the MPUC in an order dated January 9, 2023, outlines its clean-energy transition plans through 2035. These plans include expanding its renewable energy supply to 70 percent by 2030, achieving coal-free operations at its facilities by 2035, and investing in a resilient and flexible transmission and distribution grid. Minnesota Power has also set a target to achieve an 80 percent reduction in carbon emissions by 2035 compared to 2005 levels. As part of these plans, Minnesota Power anticipates adding up to 700 MW of new wind and solar energy resources, and ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. Minnesota Power’s plans recognize that advances in technology will play a significant role in completing its transition to carbon-free energy supply, reliably and affordably.
In recent years, Minnesota Power has transformed its energy supply from more than a 95 percent reliance on coal to become a leader in the nation’s clean-energy transformation. Since 2013, the company has closed or converted seven of its nine coal-fired units and added nearly 900 megawatts of renewable energy sources. Additionally, Minnesota Power has been a leader in energy conservation, surpassing the state’s conservation goals each year for the past decade.
On February 7, 2023, the Minnesota Governor signed into law legislation that updates the state’s renewable energy standard and requires Minnesota electric utilities to source retail sales with 100 percent carbon-free energy by 2040. The Company is evaluating the law to identify challenges and opportunities it could present. (See Regulated Operations – Minnesota Legislation.)
ALLETE is also committed to earning a financial return that rewards our shareholders, allows for reinvestment in our businesses, and sustains growth. ALLETE is predominately a regulated utility through Minnesota Power, SWL&P, and an investment in ATC. ALLETE’s strategy is to remain predominately a regulated utility while investing in ALLETE Clean Energy and New Energy and its Corporate and Other businesses to complement its regulated businesses, balance exposure to the utility’s industrial customers, and provide potential long-term earnings growth.
Regulated Operations includes our regulated utilities, Minnesota Power and SWL&P, as well as our investment in ATC, a Wisconsin-based regulated utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. Minnesota Power provides regulated utility electric service in northeastern Minnesota to approximately 150,000 retail customers. Minnesota Power also has 14 non-affiliated municipal customers in Minnesota. SWL&P is a Wisconsin utility and a wholesale customer of Minnesota Power. SWL&P provides regulated utility electric, natural gas and water service in northwestern Wisconsin to approximately 15,000 electric customers, 13,000 natural gas customers and 10,000 water customers. Our regulated utility operations include retail and wholesale activities under the jurisdiction of state and federal regulatory authorities. (See Note 4. Regulatory Matters.)
ALLETE Clean Energy focuses on developing, acquiring, and operating clean and renewable energy projects. ALLETE Clean Energy currently owns and operates, in seven states, more than 1,200 MW of nameplate capacity wind energy generation with a majority contracted under PSAs of various durations. In addition, ALLETE Clean Energy engages in the development of wind energy facilities to operate under long-term PSAs or for sale to others upon completion. ALLETE Clean Energy currently has approximately 100 MW of wind energy facilities under contract to be sold to others.
ALLETE, Inc. 2022 Form 10-K
7
Overview (Continued)
Corporate and Other is comprised of New Energy, a renewable development company; our investment in Nobles 2, an entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota; South Shore Energy, our non-rate regulated, Wisconsin subsidiary developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility; BNI Energy, our coal mining operations in North Dakota; ALLETE Properties, our legacy Florida real estate investment; other business development and corporate expenditures; unallocated interest expense; a small amount of non-rate base generation; land holdings in Minnesota; and earnings on cash and investments.
ALLETE is incorporated under the laws of Minnesota. Our corporate headquarters are in Duluth, Minnesota. Statistical information is presented as of December 31, 2022, unless otherwise indicated. All subsidiaries are wholly-owned unless otherwise specifically indicated. References in this report to “we,” “us” and “our” are to ALLETE and its subsidiaries, collectively.
| | | | | | | | | | | |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| | | |
Consolidated Operating Revenue – Millions (a) | $1,570.7 | | $1,419.2 | | $1,169.1 | |
| | | |
| Percentage of Consolidated Operating Revenue | | | |
| Regulated Operations | 80 | % | 87 | % | 84 | % |
| ALLETE Clean Energy | 8 | % | 6 | % | 7 | % |
Corporate and Other (a) | 12 | % | 7 | % | 9 | % |
| | 100 | % | 100 | % | 100 | % |
(a) 2022 includes revenue from New Energy, which was acquired in the second quarter of 2022. (See Note. 5 Acquisitions.)
For a detailed discussion of results of operations and trends, see Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations. For business segment information, see Note 1. Operations and Significant Accounting Policies and Note 14. Business Segments.
ALLETE, Inc. 2022 Form 10-K
8
REGULATED OPERATIONS
Electric Sales / Customers
| | | | | | | | | | | | | | | | | | | | |
| Regulated Utility Kilowatt-hours Sold | | | | | | |
| Year Ended December 31 | 2022 | % | 2021 | % | 2020 | % |
| Millions | | | | | | |
| Retail and Municipal | | | | | | |
| Residential | 1,148 | | 9 | | 1,135 | | 7 | | 1,134 | | 9 | |
| Commercial | 1,359 | | 11 | | 1,359 | | 9 | | 1,306 | | 10 | |
| Industrial | 6,745 | | 52 | | 7,196 | | 47 | | 6,192 | | 47 | |
| Municipal | 540 | | 4 | | 590 | | 4 | | 584 | | 4 | |
| Total Retail and Municipal | 9,792 | | 76 | | 10,280 | | 67 | | 9,216 | | 70 | |
| Other Power Suppliers | 3,149 | | 24 | | 5,102 | | 33 | | 4,039 | | 30 | |
| Total Regulated Utility Kilowatt-hours Sold | 12,941 | | 100 | | 15,382 | | 100 | | 13,255 | | 100 | |
Industrial Customers. In 2022, industrial customers represented 52 percent of total regulated utility kWh sales. Our industrial customers are primarily in the taconite mining, paper, pulp and secondary wood products, and pipeline industries.
The COVID-19 pandemic and related governmental responses led to a disruption of economic activity. This disruption resulted in reduced sales and revenue from industrial customers in 2020 as many industrial customers operated at reduced levels or were temporarily closed or idled during 2020. Sales to our industrial customers in 2021 were similar to levels prior to the COVID-19 pandemic. In 2022 Cliffs decided to idle all production at its Northshore mine until at least April 2023.
| | | | | | | | | | | | | | | | | | | | |
| Industrial Customer Kilowatt-hours Sold | | | | | | |
| Year Ended December 31 | 2022 | % | 2021 | % | 2020 | % |
| Millions | | | | | | |
| Taconite | 4,713 | | 70 | | 5,281 | | 73 | | 4,296 | | 69 | |
| Paper, Pulp and Secondary Wood Products | 735 | | 11 | | 702 | | 10 | | 752 | | 12 | |
| Pipelines and Other Industrial | 1,297 | | 19 | | 1,213 | | 17 | | 1,144 | | 19 | |
| Total Industrial Customer Kilowatt-hours Sold | 6,745 | | 100 | | 7,196 | | 100 | | 6,192 | | 100 | |
Six taconite facilities served by Minnesota Power made up approximately 85 percent of 2021 iron ore pellet production in the U.S. according to data from the Minnesota Department of Revenue 2022 Mining Tax Guide. These taconite facilities are owned by Cliffs and USS Corporation. (See Large Power Customer Contracts.) Sales to taconite customers represented 4,713 million kWh, or 70 percent of total industrial customer kWh sales in 2022. Taconite, an iron‑bearing rock of relatively low iron content, is abundantly available in northern Minnesota and an important domestic source of raw material for the steel industry. Taconite processing plants use large quantities of electric power to grind the iron-bearing rock, and agglomerate and pelletize the iron particles into taconite pellets.
Minnesota Power’s taconite customers are capable of producing approximately 41 million tons of taconite pellets annually. Taconite pellets produced in Minnesota are primarily shipped to North American steel making facilities that are part of the integrated steel industry, which continue to lead the world in environmental performance among steelmaking countries. According to the U.S. Department of Energy, steel production in the U.S. is the most energy efficient of any major steel producing country. Steel produced from these North American facilities is used primarily in the manufacture of automobiles, appliances, tubular applications for all industries, and in the construction industry. Steel is also a critical component of the clean energy transformation underway today. The demand for more renewable energy and the need for additional infrastructure to transport green energy from the point of generation to the end user both require steel. Historically, less than 10 percent of Minnesota taconite production has been exported outside of North America.
ALLETE, Inc. 2022 Form 10-K
9
REGULATED OPERATIONS (Continued)
Industrial Customers (Continued)
There has been a general historical correlation between U.S. steel production and Minnesota taconite production. The American Iron and Steel Institute, an association of North American steel producers, reported that U.S. raw steel production operated at approximately 78 percent of capacity in 2022 (82 percent in 2021 and 68 percent in 2020). The World Steel Association, an association of steel producers, national and regional steel industry associations, and steel research institutes representing approximately 85 percent of world steel production, projected U.S. steel consumption in 2023 will increase by approximately 2 percent compared to 2022.
The following table reflects Minnesota Power’s taconite customers’ production levels for the past ten years:
| | | | | | | | |
| Minnesota Power Taconite Customer Production |
| Year | | Tons (Millions) |
| 2022* | | 32 |
| 2021 | | 39 |
| 2020 | | 30 |
| 2019 | | 37 |
| 2018 | | 39 |
| 2017 | | 38 |
| 2016 | | 28 |
| 2015 | | 31 |
| 2014 | | 39 |
| 2013 | | 37 |
| Source: Minnesota Department of Revenue 2022 Mining Tax Guide for years 2013 - 2021. |
| * Preliminary data from the Minnesota Department of Revenue. |
Minnesota Power’s taconite customers may experience annual variations in production levels due to such factors as economic conditions, short-term demand changes or maintenance outages. We estimate that a one million ton change in Minnesota Power’s taconite customers’ production would impact our annual earnings per share by approximately $0.04, net of expected power marketing sales at current prices. Changes in wholesale electric prices or customer contractual demand nominations could impact this estimate. Minnesota Power proactively sells power in the wholesale power markets that is temporarily not required by industrial customers to optimize the value of its generating facilities. Long-term reductions in taconite production or a permanent shut down of a taconite customer may lead Minnesota Power to file a general rate case to recover lost revenue.
In addition to serving the taconite industry, Minnesota Power serves a number of customers in the paper, pulp and secondary wood products industry, which represented 735 million kWh, or 11 percent of total industrial customer kWh sales in 2022. Minnesota Power also has an agreement to provide steam for one paper and pulp customer for use in the customer’s operations. The major paper and pulp mills we serve reported operating at similar levels in 2022 compared to 2021. Verso Corporation indefinitely idled its paper mill in Duluth, Minnesota, which it subsequently sold to ST Paper in May 2021. (See Outlook – Regulated Operations – Industrial Customers and Prospective Additional Load – Paper, Pulp and Secondary Wood Products – ST Paper.)
Large Power Customer Contracts. Minnesota Power had seven Large Power Customer contracts as of December 31, 2022, each serving requirements of 10 MW or more of customer load. The customers as of December 31, 2022 consisted of six taconite facilities owned by Cliffs and USS Corporation as well as three paper and pulp mills. Certain facilities with common ownership are served under combined contracts.
ALLETE, Inc. 2022 Form 10-K
10
REGULATED OPERATIONS (Continued)
Large Power Customer Contracts (Continued)
Large Power Customer contracts require Minnesota Power to have a certain amount of generating capacity available. In turn, each Large Power Customer is required to pay a minimum monthly demand charge that covers the fixed costs associated with having this capacity available to serve the customer, including a return on common equity. Most contracts allow customers to establish the level of megawatts subject to a demand charge on a three- to four-month basis and require that a portion of their megawatt needs be committed on a take-or-pay basis for at least a portion of the term of the agreement. In addition to the demand charge, each Large Power Customer is billed an energy charge for each kWh used that recovers the variable costs incurred in generating electricity. Five of the Large Power Customer contracts have interruptible service which provides a discounted demand rate in exchange for the ability to interrupt the customers during system emergencies. Minnesota Power also provides incremental production service for customer demand levels above the contractual take-or-pay levels. There is no demand charge for this service and energy is priced at an increment above Minnesota Power’s cost. Incremental production service is interruptible.
All contracts with Large Power Customers continue past the contract termination date unless the required advance notice of cancellation has been given. The required advance notice of cancellation varies from two to four years. Such contracts reduce the impact on earnings that otherwise would result from significant reductions in kWh sales to such customers. Large Power Customers are required to take all of their purchased electric service requirements from Minnesota Power for the duration of their contracts. The rates and corresponding revenue associated with capacity and energy provided under these contracts are subject to change through the same regulatory process governing all retail electric rates. (See Regulatory Matters – Electric Rates.)
Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates. These customers receive estimated bills or make weekly prepayments based on Minnesota Power’s estimate of the customer’s energy usage, forecasted energy prices and fuel adjustment clause estimates. Minnesota Power’s taconite‑producing Large Power Customers have generally predictable energy usage on a week-to-week basis and any differences that occur are trued-up the following month.
Contract Status for Minnesota Power Large Power Customers
As of December 31, 2022 | | | | | | | | | | | | | | |
| Customer | Industry | Location | Ownership | Earliest
Termination Date |
Cliffs – Minorca Mine (a) | Taconite | Virginia, MN | Cliffs | December 31, 2026 |
Hibbing Taconite (a) | Taconite | Hibbing, MN | 85.3% Cliffs
14.7% USS Corporation | December 31, 2026 |
| United Taconite and Northshore Mining | Taconite | Eveleth, MN and Babbitt, MN | Cliffs | December 31, 2026 |
USS Corporation (USS – Minnesota Ore) (a)(b) | Taconite | Mtn. Iron, MN and Keewatin, MN | USS Corporation | December 31, 2026 |
Boise, Inc. (a) | Paper | International Falls, MN | Packaging Corporation of America | December 31, 2026 |
| UPM Blandin | Paper | Grand Rapids, MN | UPM-Kymmene Corporation | December 31, 2029 |
| | | | |
Sappi Cloquet LLC (a) | Paper and Pulp | Cloquet, MN | Sappi Limited | December 31, 2026 |
(a)The contract will terminate four years from the date of written notice from either Minnesota Power or the customer. No notice of contract cancellation has been given by either party. Thus, the earliest date of cancellation is December 31, 2026.
(b)USS Corporation owns both the Minntac Plant in Mountain Iron, MN, and the Keewatin Taconite Plant in Keewatin, MN.
ALLETE, Inc. 2022 Form 10-K
11
REGULATED OPERATIONS (Continued)
Residential and Commercial Customers. In 2022, residential and commercial customers represented 20 percent of total regulated utility kWh sales.
Municipal Customers. In 2022, municipal customers represented 4 percent of total regulated utility kWh sales.
Minnesota Power’s wholesale electric contracts with 14 non-affiliated municipal customers in Minnesota have termination dates ranging from 2029 through 2037, with a majority of contracts expiring in 2029. One of these wholesale contracts includes a termination clause requiring a three-year notice to terminate. (See Note 4. Regulatory Matters.)
Other Power Suppliers. The Company also enters into off-system sales with Other Power Suppliers. These sales are at market‑based prices into the MISO market on a daily basis or through bilateral agreements of various durations.
Our PSAs are detailed in Note 9. Commitments, Guarantees and Contingencies, with additional disclosure provided in the following paragraphs.
Minnkota Power PSA. Minnesota Power has a PSA with Minnkota Power where Minnesota Power is selling a portion of its entitlement from Square Butte to Minnkota Power, resulting in Minnkota Power’s net entitlement increasing and Minnesota Power’s net entitlement decreasing until Minnesota Power’s share is eliminated at the end of 2025. Of Minnesota Power’s 50 percent output entitlement, it sold approximately 32 percent to Minnkota Power in 2022 (28 percent in 2021 and in 2020). Minnkota Power’s net entitlement increases to approximately 37 percent in 2023, 41 percent in 2024, 46 percent in 2025 and 50 percent in 2026. (See Power Supply – Long-Term Purchased Power.)
Silver Bay Power PSA. Minnesota Power has a PSA with Silver Bay Power through 2031 to supply the full energy requirements for Silver Bay Power. Silver Bay Power supplies approximately 90 MW of load to Northshore Mining, an affiliate of Silver Bay Power.
Hibbing Public Utilities. In April 2022, Minnesota Power entered into a new long-term Power Purchase and Market Energy Service Agreement with Hibbing Public Utilities for the period of June 1, 2022, through May 31, 2027. The agreement replaced the previous wholesale electric contract between Hibbing Public Utilities and Minnesota Power.
Seasonality
The operations of our industrial customers, which make up a large portion of our electric sales, are not typically subject to significant seasonal variations. (See Electric Sales / Customers.) As a result, Minnesota Power is generally not subject to significant seasonal fluctuations in electric sales; however, Minnesota Power and SWL&P electric and natural gas sales to other customers may be affected by seasonal differences in weather. In general, peak electric sales occur in the winter and summer months with fewer electric sales in the spring and fall months. Peak sales of natural gas generally occur in the winter months. Additionally, our regulated utilities have historically generated fewer sales and less revenue when weather conditions are milder in the winter and summer.
Power Supply
In order to meet its customers’ electric requirements, Minnesota Power utilizes a mix of its own generation and purchased power. As of December 31, 2022, approximately 50 percent of Minnesota Power’s power supply for its retail and municipal customers in Minnesota was provided by renewable energy sources. This was enabled by the completion of the 250 MW Nobles 2 wind energy facility in December 2020 and the GNTL in June 2020, which is used to deliver 250 MW of hydroelectric energy from Manitoba Hydro. Minnesota Power’s remaining operating coal-fired facilities are Boswell Units 3 and 4, which Minnesota Power plans to cease coal operations at by 2030 and 2035, respectively. (See Regulatory Matters.) The following table reflects Minnesota Power’s generating capabilities as of December 31, 2022, and total electrical supply for 2022. Minnesota Power had an annual net peak load of 1,556 MW on January 7, 2022.
ALLETE, Inc. 2022 Form 10-K
12
REGULATED OPERATIONS (Continued)
Power Supply (Continued)
| | | | | | | | | | | | | | | | | | | | |
| | | | | Year Ended |
| Unit | Year | Net | | December 31, 2022 |
| Regulated Utility Power Supply | No. | Installed | Capability | | Generation and Purchases |
| | | | MW | | MWh | % |
| Coal-Fired | | | | | | |
Boswell Energy Center (a) | 3 | 1973 | 352 | | | |
| in Cohasset, MN | 4 | 1980 | 468 | (b) | | |
| | | | 820 | | 4,520,828 | | 33.9 | |
| Taconite Harbor Energy Center | 1 & 2 | 1957 | 150 | (c) | — | | — | |
| | | | | | |
| | | | | | |
| Total Coal-Fired | | | 970 | | 4,520,828 | | 33.9 | |
| Biomass Co-Fired / Natural Gas | | | | | | |
| Hibbard Renewable Energy Center in Duluth, MN | 3 & 4 | 1949, 1951 | 60 | | | 134,049 | | 1.0 | |
| | | | | | |
| Laskin Energy Center in Hoyt Lakes, MN | 1 & 2 | 1953 | 98 | | | 122,277 | | 0.9 | |
| Total Biomass Co-Fired / Natural Gas | | | 158 | | | 256,326 | | 1.9 | |
Hydro (d) | | | | | | |
| Group consisting of ten stations in MN | Multiple | Multiple | 120 | | | 546,876 | | 4.1 | |
Wind (e) | | | | | | |
| Taconite Ridge Energy Center in Mtn. Iron, MN | Multiple | 2008 | 25 | | | 62,168 | | 0.5 | |
| Bison Wind Energy Center in Oliver and Morton Counties, ND | Multiple | 2010-2014 | 497 | | | 1,566,952 | | 11.8 | |
| Total Wind | | | 522 | | | 1,629,120 | | 12.3 | |
Solar (f) | | | | | | |
| Group consisting of two solar arrays in MN | Multiple | Multiple | 10 | | | 16,169 | | 0.1 | |
| Total Generation | | | 1,780 | | | 6,969,319 | | 52.3 | |
| | | | | | |
| Long-Term Purchased Power | | | | | | |
Lignite Coal - Square Butte near Center, ND (g) | | | | | 1,192,480 | | 8.9 | |
| Wind - Oliver Wind I and II in Oliver County, ND | | | | | 407,253 | | 3.0 | |
Wind - Nobles 2 in Nobles County, MN (h) | | | | | 1,091,676 | | 8.2 | |
| Hydro - Manitoba Hydro in Manitoba, Canada | | | | | 1,460,000 | | 11.0 | |
| Total Long-Term Purchased Power | | | | | 4,151,409 | | 31.1 | |
Other Purchased Power (i) | | | | | 2,210,192 | | 16.6 | |
Total Purchased Power | | | | | 6,361,601 | | 47.7 | |
Total Regulated Utility Power Supply | | | | | 13,330,920 | | 100.0 | |
(a) Minnesota Power anticipates ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. (See Regulatory Matters.)
(b)Boswell Unit 4 net capability shown above reflects Minnesota Power’s ownership percentage of 80 percent. WPPI Energy owns 20 percent of Boswell Unit 4. (See Note 3. Jointly-Owned Facilities and Assets.)
(c)Taconite Harbor Units 1 and 2 were idled in 2016 and are planned to be retired in the first quarter of 2023. (See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Outlook – EnergyForward.)
(d)Hydro consists of 10 stations with 34 generating units.
(e)Taconite Ridge consists of 10 WTGs and Bison consists of 165 WTGs.
(f)Solar includes the 10 MW Camp Ripley Solar Array near Little Falls, MN, and a 40 kW community solar garden in Duluth, MN.
(g)Minnesota Power has a PSA with Minnkota Power whereby Minnesota Power is selling a portion of its entitlement from Square Butte to Minnkota Power. (See Electric Sales / Customers – Minnkota Power PSA.)
(h)See Item 1. Business – Corporate and Other – Investment in Nobles 2.
(i)Includes short-term market purchases in the MISO market and from Other Power Suppliers.
ALLETE, Inc. 2022 Form 10-K
13
REGULATED OPERATIONS (Continued)
Power Supply (Continued)
Fuel. Minnesota Power purchases low-sulfur, sub-bituminous coal from the Powder River Basin region located in Montana and Wyoming. Coal consumption in 2022 for electric generation at Minnesota Power’s coal-fired generating stations was 2.7 million tons (2.7 million tons in 2021; 2.2 million tons in 2020). As of December 31, 2022, Minnesota Power had coal inventories of 0.8 million tons (0.4 million tons as of December 31, 2021). Minnesota Power has coal supply agreements providing for the purchase of a significant portion of its coal requirements through December 2023. In 2023, Minnesota Power expects to obtain coal under these coal supply agreements and in the spot market. Minnesota Power continues to explore other future coal supply options and believes that adequate supplies of low-sulfur, sub-bituminous coal will continue to be available.
Minnesota Power also has coal transportation agreements in place for the delivery of a significant portion of its coal requirements through December 2024. The costs of fuel and related transportation costs for Minnesota Power’s generation are recoverable from Minnesota Power’s utility customers through the fuel adjustment clause.
| | | | | | | | | | | |
| Coal Delivered to Minnesota Power |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Average Price per Ton | $39.98 | | $39.51 | | $34.94 | |
| Average Price per MBtu | $2.25 | | $2.18 | | $1.93 | |
Long-Term Purchased Power. Minnesota Power has contracts to purchase capacity and energy from various entities, including output from certain coal, wind, hydro and solar generating facilities.
Our PPAs are detailed in Note 9. Commitments, Guarantees and Contingencies, with additional disclosure provided in the following paragraph.
Square Butte PPA. Under the PPA with Square Butte that extends through 2026, Minnesota Power is entitled to 50 percent of the output of Square Butte’s 455 MW coal-fired generating unit. (See Note 9. Commitments, Guarantees and Contingencies.) BNI Energy mines and sells lignite coal to Square Butte. This lignite supply is sufficient to provide fuel for the anticipated useful life of the generating unit. Square Butte’s cost of lignite consumed in 2022 was approximately $2.05 per MBtu ($1.94 per MBtu in 2021; $1.75 per MBtu in 2020). (See Electric Sales / Customers – Minnkota Power PSA.)
Manitoba Hydro. Minnesota Power has two long-term PPAs with Manitoba Hydro. The first PPA provides for Minnesota Power to purchase 250 MW of capacity and energy from Manitoba Hydro through May 2035. The second PPA provides for Minnesota Power to purchase up to 133 MW of energy from Manitoba Hydro through June 2040. A third PPA, which expired in April 2022 was an energy-only agreement, which primarily consisted of surplus hydro energy on Manitoba Hydro’s system that was delivered to Minnesota Power on a non-firm basis.
Transmission and Distribution
We have electric transmission and distribution lines of 500 kV (232 miles), 345 kV (241 miles), 250 kV (466 miles), 230 kV (715 miles), 161 kV (43 miles), 138 kV (8 miles), 115 kV (1,376 miles) and less than 115 kV (6,416 miles). We own and operate 162 substations with a total capacity of 10,116 megavoltamperes. Some of our transmission and distribution lines interconnect with other utilities.
Great Northern Transmission Line. As a condition of the 250 MW long-term PPA entered into with Manitoba Hydro, construction of additional transmission capacity was required. As a result, Minnesota Power constructed the GNTL, an approximately 220‑mile 500-kV transmission line between Manitoba and Minnesota’s Iron Range that was proposed by Minnesota Power and Manitoba Hydro in order to strengthen the electric grid, enhance regional reliability and promote a greater exchange of sustainable energy. In June 2020, Minnesota Power placed the GNTL into service with project costs of approximately $310 million incurred by Minnesota Power. Total project costs, including those costs contributed by a subsidiary of Manitoba Hydro, totaled approximately $660 million. The 250 MW PPA with Manitoba Hydro commenced when the GNTL was placed into service.
ALLETE, Inc. 2022 Form 10-K
14
REGULATED OPERATIONS (Continued)
Investment in ATC
Our wholly-owned subsidiary, ALLETE Transmission Holdings, owns approximately 8 percent of ATC, a Wisconsin-based utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. We account for our investment in ATC under the equity method of accounting. As of December 31, 2022, our equity investment in ATC was $165.4 million ($154.5 million as of December 31, 2021). (See Note 6. Equity Investments.)
ATC’s authorized return on equity is 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization, based on a 2020 FERC order which is subject to various outstanding legal challenges related to the return on equity calculation and refund period ordered by the FERC. On August 9, 2022, the U.S. Court of Appeals for the District of Columbia Circuit vacated and remanded the 2020 FERC order back to the FERC. As a result of this decision, ATC recorded a reserve in the third quarter of 2022 for anticipated refunds to its customers for approximately $31 million of which our share was approximately $2.4 million pre-tax. We cannot predict the return on equity the FERC will ultimately authorize in the remanded proceeding.
In addition, the FERC issued a Notice of Proposed Rulemaking in April 2021 proposing to limit the 50 basis point incentive adder for participation in a regional transmission organization to only the first three years of membership in such an organization. If this proposal is adopted, our equity in earnings from ATC would be reduced by approximately $1 million pre-tax annually.
ATC’s most recent 10-year transmission assessment, which covers the years 2022 through 2031, identifies a need for between $5.1 billion and $6.2 billion in transmission system investments. These investments by ATC, if undertaken, are expected to be funded through a combination of internally generated cash, debt and investor contributions. As opportunities arise, we plan to make additional investments in ATC through general capital calls based upon our pro rata ownership interest in ATC.
Properties
Our Regulated Operations businesses own office and service buildings, an energy control center, repair shops, electric plants, transmission facilities and storerooms in various localities in Minnesota, Wisconsin and North Dakota. All of the electric plants are subject to mortgages, which collateralize the outstanding first mortgage bonds of Minnesota Power and SWL&P. Most of the generating plants and substations are located on real property owned by Minnesota Power or SWL&P, subject to the lien of a mortgage, whereas most of the transmission and distribution lines are located on real property owned by others with appropriate easement rights or necessary permits from governmental authorities. WPPI Energy owns 20 percent of Boswell Unit 4. WPPI Energy has the right to use our transmission line facilities to transport its share of Boswell generation. (See Note 3. Jointly-Owned Facilities and Assets.)
Regulatory Matters
We are subject to the jurisdiction of various regulatory authorities and other organizations. Regulatory matters and proceedings are detailed in Note 4. Regulatory Matters, with a summary included in the following paragraphs.
Electric Rates. All rates and contract terms in our Regulated Operations are subject to approval by applicable regulatory authorities. Minnesota Power and SWL&P design their retail electric service rates based on cost of service studies under which allocations are made to the various classes of customers as approved by the MPUC or the PSCW. Nearly all retail sales include billing adjustment clauses, which may adjust electric service rates for changes in the cost of fuel and purchased energy, recovery of current and deferred conservation improvement program expenditures and recovery of certain transmission, renewable and environmental investments.
Minnesota Public Utilities Commission. The MPUC has regulatory authority over Minnesota Power’s retail service area in Minnesota, retail rates, retail services, capital structure, issuance of securities and other matters. Minnesota Power’s current retail rates through 2021 were based on a 2018 MPUC retail rate order that allows for a 9.25 percent return on common equity and a 53.81 percent equity ratio. The resolution of Minnesota Power’s 2020 general rate case did not change the allowed return on equity or equity ratio. (See 2020 Minnesota General Rate Case.) As authorized by the MPUC, Minnesota Power also recognizes revenue under cost recovery riders for transmission and renewable investments.
ALLETE, Inc. 2022 Form 10-K
15
REGULATED OPERATIONS (Continued)
Regulatory Matters (Continued)
2020 Minnesota General Rate Case. In November 2019, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 10.6 percent for retail customers.
In April 2020, Minnesota Power filed a request with the MPUC that proposed a resolution of Minnesota Power’s 2020 general rate case. Key components of our proposal included removing the power marketing margin credit in base rates and reflecting actual power marketing margins in the fuel adjustment clause effective May 1, 2020; refunding to customers interim rates collected through April 2020; increasing customer rates 4.1 percent compared to the 5.8 percent increase reflected in interim rates; and a provision that Minnesota Power would not file another rate case until at least November 1, 2021, unless certain events occur. In a June 2020 order, the MPUC approved Minnesota Power’s petition and proposal to resolve and withdraw the general rate case. Effective May 1, 2020, customer rates were set at an increase of 4.1 percent with the removal of the power marketing margin credit from base rates. Actual power marketing margins are now reflected in the fuel adjustment clause. Reserves for interim rates of $11.7 million were recorded in the second quarter of 2020 and refunded in the third and fourth quarters of 2020.
2022 Minnesota General Rate Case. On November 1, 2021, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 18 percent for retail customers. The rate filing seeks a return on equity of 10.25 percent and a 53.81 percent equity ratio. On an annualized basis, the requested final rate increase would generate approximately $108 million in additional revenue. In orders dated December 30, 2021, the MPUC accepted the filing as complete and authorized an annual interim rate increase beginning January 1, 2022, with approximately $80 million expected to be collected in cash and approximately $8 million of interim rates for residential customers deferred with a final determination on recovery at the end of the rate case.
At a hearing on January 23, 2023, the MPUC made determinations regarding Minnesota Power’s general rate case including allowing a return on common equity of 9.65 percent and a 52.50 percent equity ratio. Upon commencement of final rates, we expect additional revenue from base rates of approximately $60 million and an additional $10 million in revenue recognized under cost recovery riders on an annualized basis, subject to final written order and reconsideration. Final rates are expected to commence in the third quarter of 2023; interim rates will be collected through this period with reserves recorded as necessary. As a result of the MPUC’s determinations made on January 23, 2023, Minnesota Power has recorded a reserve for an interim rate refund of approximately $18 million pre-tax as of December 31, 2022, which is subject to MPUC approval of Minnesota Power’s refund calculation. In addition, Minnesota Power recorded a charge of approximately $8 million pre-tax to write-off the deferred portion of residential customer interim rates. Minnesota Power also recorded additional revenue of approximately $9 million pre-tax for an increase in expected recoveries under its cost recovery riders.
Minnesota Power Land Sales. In August 2020, Minnesota Power filed a petition with the MPUC for approval to sell land that surrounds several reservoirs on its hydroelectric system and is no longer required to maintain its operations. The land has an estimated value of approximately $100 million, and Minnesota Power proposed to credit ratepayers the net proceeds from the sales in a future rate case or through its renewable resources rider to mitigate future rate increases. In an order dated November 18, 2021, the MPUC authorized the land sales and directed the net proceeds to be refunded to ratepayers subject to certain conditions and required compliance filings.
2021 Integrated Resource Plan. On February 1, 2021, Minnesota Power filed its latest IRP, which was approved by the MPUC in an order dated January 9, 2023. The approved IRP, which reflects a joint agreement reached with various stakeholders, outlines Minnesota Power’s clean-energy transition plans through 2035. These plans include expanding its renewable energy supply, achieving coal-free operations at its facilities by 2035, and investing in a resilient and flexible transmission and distribution grid. As part of these plans, Minnesota Power anticipates adding up to 700 MW of new wind and solar energy resources, and ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. Minnesota Power’s plans recognize that advances in technology will play a significant role in completing its transition to carbon-free energy supply, reliably and affordably. Minnesota Power is expected to file its next IRP by March 1, 2025.
Minnesota Power has a vision to deliver 100 percent carbon-free energy to customers by 2050, continuing its commitment to climate, customers and communities through its EnergyForward strategy. This vision builds on Minnesota Power’s achievement, in 2020, of now providing 50 percent renewable energy to its customers.
ALLETE, Inc. 2022 Form 10-K
16
REGULATED OPERATIONS (Continued)
Regulatory Matters (Continued)
Public Service Commission of Wisconsin. The PSCW has regulatory authority over SWL&P’s retail sales of electricity, natural gas and water, issuances of securities and other matters. SWL&P’s retail rates through 2022 were based on a December 2018 order by the PSCW that allowed for a return on equity of 10.4 percent and a 55.0 percent equity ratio.
In 2022, SWL&P filed a rate increase request with the PSCW seeking an average increase of 3.6 percent for retail customers. The filing sought an overall return on equity of 10.4 percent and a 55 percent equity ratio. On an annualized basis, the requested final rate increase would have generated an estimated $4.3 million in additional revenue. In an order dated December 20, 2022, the PSCW approved an annual increase of $3.3 million reflecting a return on equity of 10.0 percent and 55 percent equity ratio. Final rates went into effect January 1, 2023.
North Dakota Public Service Commission. The NDPSC has jurisdiction over site and route permitting of generation and transmission facilities in North Dakota.
Federal Energy Regulatory Commission. The FERC has jurisdiction over the licensing of hydroelectric projects, the establishment of rates and charges for transmission of electricity in interstate commerce, electricity sold at wholesale (including the rates for Minnesota Power’s municipal and wholesale customers), natural gas transportation, certain accounting and record‑keeping practices, certain activities of our regulated utilities and the operations of ATC. FERC jurisdiction also includes enforcement of NERC mandatory electric reliability standards. Violations of FERC rules are subject to enforcement action by the FERC including financial penalties up to $1 million per day per violation.
Regional Organizations
Midcontinent Independent System Operator, Inc. Minnesota Power, SWL&P and ATC are members of MISO, a regional transmission organization. While Minnesota Power and SWL&P retain ownership of their respective transmission assets, their transmission networks are under the regional operational control of MISO. Minnesota Power and SWL&P take and provide transmission service under the MISO open access transmission tariff. In cooperation with stakeholders, MISO manages the delivery of electric power across 15 states and the Canadian province of Manitoba.
North American Electric Reliability Corporation. The NERC has been certified by the FERC as the national electric reliability organization. The NERC ensures the reliability of the North American bulk power system. The NERC oversees six regional entities that establish requirements, approved by the FERC, for reliable operation and maintenance of power generation facilities and transmission systems. Minnesota Power is subject to these reliability requirements and can incur significant penalties for non‑compliance.
Midwest Reliability Organization (MRO). Minnesota Power and ATC are members of the MRO, one of the six regional entities overseen by the NERC. The MRO's primary responsibilities are to: ensure compliance with mandatory reliability standards by entities which own, operate or use the interconnected, international bulk power system; conduct assessments of the grid's ability to meet electricity demand in the region; and analyze regional system events. The MRO region spans the Canadian provinces of Saskatchewan and Manitoba, and all or parts of 16 states.
Minnesota Legislation
Renewable and Carbon-Free Energy Requirements. On February 7, 2023, the Minnesota Governor signed into law legislation that updates the state’s renewable energy standard and requires Minnesota electric utilities to source retail sales with 100 percent carbon-free energy by 2040. The law increases the renewable energy standard from 25 percent renewable by 2025 to 55 percent renewable by 2035, and requires investor-owned Minnesota utilities to provide 80 percent carbon-free energy by 2030, 90 percent carbon-free energy by 2035 and 100 percent carbon-free energy by 2040. The law utilizes renewable energy credits as the means to demonstrate compliance with both the carbon-free and renewable energy standards, includes an off ramp provision that enables the MPUC to protect reliability and customer costs through modification or delay of either the renewable energy standard, the carbon-free standard, or both, and streamlines development and construction of wind energy projects and transmission in Minnesota. The Company is evaluating the law to identify challenges and opportunities it could present.
As of December 31, 2022, approximately 50 percent of Minnesota Power’s power supply for its retail and municipal customers in Minnesota was provided by renewable energy sources. Minnesota Power’s plans include expanding its renewable energy supply to 70 percent renewable energy by 2030. (See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Outlook – EnergyForward.)
ALLETE, Inc. 2022 Form 10-K
17
REGULATED OPERATIONS (Continued)
Minnesota Legislation (Continued)
Minnesota Solar Energy Standard. Minnesota law requires at least 1.5 percent of total retail electric sales, excluding sales to certain customers, to be generated by solar energy. At least 10 percent of the 1.5 percent mandate must be met by solar energy generated by or procured from solar photovoltaic devices with a nameplate capacity of 40 kW or less and community solar garden subscriptions. Minnesota Power has met both parts of the solar mandate to date.
Competition
Retail electric energy sales in Minnesota and Wisconsin are made to customers in assigned service territories. As a result, most retail electric customers in Minnesota do not have the ability to choose their electric supplier. Large energy users of 2 MW and above that are located outside of a municipality are allowed to choose a supplier upon MPUC approval. Minnesota Power served seven Large Power Customers under contracts of at least 10 MW in 2022, none of which have engaged in a competitive rate process. (See Electric Sales / Customers.) No other large commercial or small industrial customers in Minnesota Power’s service territory have sought a provider outside Minnesota Power’s service territory. Retail electric and natural gas customers in Wisconsin do not have the ability to choose their energy supplier. In both states, however, electricity may compete with other forms of energy. Customers may also choose to generate their own electricity, or substitute other forms of energy for their manufacturing processes.
In 2022, 4 percent of total regulated utility kWh sales were to municipal customers in Minnesota. These customers have the right to seek an energy supply from any wholesale electric service provider upon contract expiration. Minnesota Power’s wholesale electric contract with the Nashwauk Public Utilities Commission was extended in 2020 and is effective through December 31, 2037. Minnesota Power’s wholesale electric contracts with 13 other non-affiliated municipal customers are effective through 2029. (See Electric Sales / Customers.)
The FERC has continued with its efforts to promote a competitive wholesale market through open-access electric transmission and other means. As a result, our electric sales to Other Power Suppliers and our purchases to supply our retail and wholesale load are made in a competitive market.
Franchises
Minnesota Power holds franchises to construct and maintain an electric distribution and transmission system in 95 cities. The remaining cities, villages and towns served by Minnesota Power do not require a franchise to operate. SWL&P serves customers under electric, natural gas or water franchises in 1 city and 14 villages and towns.
ALLETE CLEAN ENERGY
ALLETE Clean Energy focuses on developing, acquiring, and operating clean and renewable energy projects. ALLETE Clean Energy currently owns and operates, in seven states, more than 1,200 MW of nameplate capacity wind energy generation with a majority contracted under PSAs of various durations. In addition, ALLETE Clean Energy engages in the development of wind energy facilities to operate under long-term PSAs or for sale to others upon completion. ALLETE Clean Energy currently has approximately 100 MW of wind energy facilities under contract to be sold to others. (See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Outlook – ALLETE Clean Energy.)
ALLETE Clean Energy believes the market for renewable energy in North America is robust, driven by several factors including environmental regulation, tax incentives such as the extension of production tax credit and investment tax credits, societal expectations and continual technology advances. State renewable portfolio standards, state or federal regulations to limit GHG emissions and the extension of production tax credit and investment tax credits are examples of environmental regulation or public policy that we believe will drive renewable energy development.
ALLETE, Inc. 2022 Form 10-K
18
ALLETE CLEAN ENERGY (Continued)
ALLETE Clean Energy’s strategy includes the safe, reliable, optimal and profitable operation of its existing facilities. This includes a strong safety culture, the continuous pursuit of operational efficiencies at existing facilities and cost controls. ALLETE Clean Energy generally acquires facilities in liquid power markets and its strategy includes the exploration of PSA extensions upon expiration of existing contracts, production tax credit requalification of existing facilities or the sale of facilities.
ALLETE Clean Energy manages risk by having a diverse portfolio of assets, which includes PSA expiration, technology and geographic diversity. The current operating portfolio is subject to typical variations in seasonal wind with higher wind resources typically available in the winter months. The majority of its planned maintenance leverages this seasonality and is performed during lower wind periods. ALLETE Clean Energy’s current operating portfolio is as follows:
| | | | | | | | | | | | | | |
| Region | Wind Energy Facility | Capacity MW | PSA MW | PSA Expiration |
| East | Armenia Mountain | 101 | 100% | 2024 |
| | | | |
| | | | |
| | | | |
| Midwest | Lake Benton | 104 | 100% | 2028 |
| Storm Lake I | 108 | 100% | 2027 |
| Storm Lake II | 77 | | |
| Merchant | | 90% | n/a |
| PSA | | 10% | 2032 |
| Other | 17 | 100% | 2028 |
| South | Caddo | 303 | | |
| Merchant | | 27% | n/a |
| PSA 1 | | 66% | 2034 |
| PSA 2 | | 7% | 2034 |
| Diamond Spring | 303 | | |
| PSA 1 | | 58% | 2035 |
| PSA 2 | | 25% | 2032 |
| PSA 3 | | 16% | 2035 |
| West | Condon | 50 | 100% | (a) |
| Glen Ullin | 106 | 100% | 2039 |
| | | | |
| South Peak | 80 | 100% | 2035 |
(a)The PSA for Condon expired in 2022, and Condon is currently selling energy pursuant to a month-to-month agreement while the parties negotiate an agreement on a new PSA.
The majority of ALLETE Clean Energy’s wind operations are located on real property owned by others with easement rights or necessary consents of governmental authorities. One of ALLETE Clean Energy’s wind energy facilities is encumbered by liens against its assets securing financing. ALLETE Clean Energy’s Glen Ullin, South Peak, Diamond Spring and Caddo wind energy facilities are subject to tax equity financing structures. (See Note 1. Operations and Significant Accounting Policies.)
CORPORATE AND OTHER
New Energy
On April 15, 2022, a wholly-owned subsidiary of ALLETE acquired 100 percent of the membership interests of New Energy for a purchase price of $165.5 million. New Energy, which is headquartered in Annapolis, Maryland, is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. New Energy is a leading developer of community, commercial and industrial, and small utility-scale renewable energy projects that has completed more than 400 MW in its history, totaling more than $1 billion of capital deployed. New Energy currently has a robust project pipeline with greater than 2,000 MW of renewable projects in development across 26 different states. New Energy is involved in greenfield development as well as acquiring and completing mid-stage and late-stage renewable energy projects. New Energy will continue its current strategy of developing and operating renewable energy projects.
ALLETE, Inc. 2022 Form 10-K
19
CORPORATE AND OTHER (Continued)
Investment in Nobles 2
Our subsidiary, ALLETE South Wind, owns a 49 percent equity interest in Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20-year PPA with Minnesota Power. As of December 31, 2022, our equity investment in Nobles 2 was $157.3 million ($163.5 million at December 31, 2021). (See Note 6. Equity Investments.)
South Shore Energy
South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary, is developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting in 2027 pursuant to a capacity dedication agreement. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $700 million, of which South Shore Energy’s portion is expected to be approximately $150 million. South Shore Energy’s portion of NTEC project costs incurred through December 31, 2022, is approximately $7 million.
BNI Energy
BNI Energy is a supplier of lignite coal in North Dakota, producing approximately 4 million tons annually and has an estimated 650 million tons of lignite coal reserves. Two electric generating cooperatives, Minnkota Power and Square Butte, consume virtually all of BNI Energy’s production of lignite under cost-plus fixed fee coal supply agreements extending through December 31, 2037. (See Item 1. Business – Regulated Operations – Power Supply – Long-Term Purchased Power and Note 9. Commitments, Guarantees and Contingencies.) The mining process disturbs and reclaims between 200 and 250 acres per year. Laws require that the reclaimed land be at least as productive as it was prior to mining. As of December 31, 2022, BNI Energy’s total reclamation liability is estimated at $82.1 million, which is included in Other Non-Current Liabilities on the Consolidated Balance Sheet at its present value. These costs are included in the cost-plus fixed fee contract, for which an asset reclamation cost receivable was included in Other Non-Current Assets on the Consolidated Balance Sheet. The asset reclamation obligation is guaranteed by surety bonds and a letter of credit. (See Note 9. Commitments, Guarantees and Contingencies.)
ALLETE Properties
ALLETE Properties represents our legacy Florida real estate investment. ALLETE Properties’ major project in Florida is Town Center at Palm Coast, which consists of approximately 300 acres of land as well as various residential units and non-residential square footage. In addition to the Town Center at Palm Coast project, ALLETE Properties has approximately 500 acres of other land available for sale. (See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Outlook – Corporate and Other – ALLETE Properties.)
Seller Financing. ALLETE Properties occasionally provides seller financing to qualified buyers. As of December 31, 2022, outstanding finance receivables were $10.5 million, net of reserves, with maturities through 2027. These finance receivables accrue interest at market-based rates and are collateralized by the financed properties.
Regulation. A substantial portion of our development properties in Florida are subject to federal, state and local regulations, and restrictions that may impose significant costs or limitations on our ability to develop the properties. Much of our property is vacant land and some is located in areas where development may affect the natural habitats of various protected wildlife species or in sensitive environmental areas such as wetlands.
Non-Rate Base Generation and Miscellaneous
Corporate and Other also includes other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, land holdings in Minnesota, and earnings on cash and investments.
As of December 31, 2022, non-rate base generation consists of 29 MW of natural gas and hydro generation at Rapids Energy Center in Grand Rapids, Minnesota, which is primarily dedicated to the needs of one customer, UPM Blandin.
ALLETE, Inc. 2022 Form 10-K
20
ENVIRONMENTAL MATTERS
Our businesses are subject to regulation of environmental matters by various federal, state and local authorities. A number of regulatory changes to the Clean Air Act, the Clean Water Act and various waste management requirements have been promulgated by both the EPA and state authorities over the past several years. Minnesota Power’s facilities are subject to additional requirements under many of these regulations. Minnesota Power is reshaping its generation portfolio, over time, to reduce its reliance on coal, has installed cost-effective emission control technology, and advocates for sound science and policy during rulemaking implementation.
We consider our businesses to be in substantial compliance with currently applicable environmental regulations and believe all necessary permits have been obtained. We anticipate that with many state and federal environmental regulations and requirements finalized, or to be finalized in the near future, potential expenditures for future environmental matters may be material and require significant capital investments. Minnesota Power has evaluated various environmental compliance scenarios using possible outcomes of environmental regulations to project power supply trends and impacts on customers.
We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated based on current law and existing technologies. Accruals are adjusted as assessment and remediation efforts progress, or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the Consolidated Balance Sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are expensed unless recoverable in rates from customers. (See Note 9. Commitments, Guarantees and Contingencies.)
HUMAN CAPITAL MANAGEMENT
The Company’s key human capital management objectives are to attract, recognize and retain high quality talent, align with strategic business objectives and support the Company’s values. To support these objectives, the Company’s programs are designed to develop talent; reward and support employees through competitive compensation programs and benefit plans; enhance the Company’s culture through efforts aimed at making the workplace more engaging, safe and inclusive; and acquire talent and leverage internal opportunities to create a high-performing, diverse workforce. Our management, the ALLETE Board of Directors Executive Compensation and Human Capital Committee, and our Board of Directors as a whole play key roles in reviewing and overseeing our human capital practices.
As of December 31, 2022, ALLETE had 1,494 employees, of which 1,467 were full-time. We also respect employees’ freedom of association and their right to collectively organize. As of December 31, 2022, Minnesota Power and SWL&P have an aggregate of 484 employees covered under collective bargaining agreements, of which most are members of the International Brotherhood of Electrical Workers (IBEW) Local 31. The current labor agreements with IBEW Local 31 expire on April 30, 2023 for Minnesota Power and January 31, 2024 for SWL&P. BNI Energy has 127 employees that are members of IBEW Local 1593. The current labor agreement with IBEW Local 1593 expires on March 31, 2023.
ALLETE’s Human Rights Statement confirms our commitment to the advancement and protection of human rights, consistent with U.S. human rights laws and the general principles in the International Labour Organization Conventions.
Integrity. Integrity is a foundational, shared value at ALLETE, is important to ALLETE’s business and operations, and enables our success. The Company has a written Code of Business Conduct that applies to all of our employees, directors of ALLETE, contractors, vendors, and others who do business with or on behalf of ALLETE.
Health and Safety. The success of our business is fundamentally connected to the well-being of our people. Our journey to Zero Injury starts with a culture that is open and transparent. We encourage all employees to report injuries, near misses, and good catches, so that we can learn and share with others throughout the Company in an effort to improve safety performance. Leaders have regular safety conversations with employees, where hazard identification and controls are discussed to ensure work is being performed safely. Conversations are documented and the data is collected and analyzed for trends. To monitor progress, the Company uses leading and lagging indicators to analyze injury trends, safety participation and other data to make better decision on safety practices.
ALLETE, Inc. 2022 Form 10-K
21
HUMAN CAPITAL MANAGEMENT (Continued)
Talent Attraction, Retention and Development. For more than a century, ALLETE has been successful because of our ability to attract and retain high-quality people who demonstrate our shared values. We engage in workforce planning, and succession planning, while building a robust talent pipeline and monitoring turnover.
We recognize and support the growth and development of our employees and offer opportunities to participate in internal and external learning programs. Our internal talent development programs provide employees with the resources they need to develop proficiency in their role, help achieve their career goals and build leadership skills. We are focusing initiatives on programs to expand the diversity of new hires and updating on-the-job trainings—including apprenticeships and scholarships aimed at bridging opportunity gaps—as we recognize the importance of a strong talent pipeline. In addition to role specific training, targeted training also includes respect in the workplace, cyber awareness, safety, integrity and leadership development.
Compensation and Benefits. Our competitive compensation package gives employees flexibility, choices and opportunities. Competitive compensation is important for the Company to attract and retain a qualified workforce to successfully manage our business and achieve our business objectives. We also strive to ensure pay equity amongst diverse employees performing equal or substantially similar work. Periodically, we review the median pay of our male and female employees as well as employees from diverse backgrounds.
Diversity, Equity and Inclusion. Increasing diversity enriches our workforce culture at ALLETE. Our employees are operating in an increasingly diverse society. In order to be accountable to our employees and stakeholders, we strive to have a workforce that reflects the diversity of the communities we serve, promotes inclusivity and is equitable.
At ALLETE, we want to ensure that we have a workplace culture where we treat each other with fairness, dignity and respect. The Company has a respect in the workplace initiative, which includes education as well as ongoing discussions focused on building respectful relationships and managing bias. We continue our efforts in crafting a framework to strengthen ALLETE’s diversity, equity and inclusion efforts in the areas of: workforce, supply chain, communications, customers, and ALLETE as a community citizen. ALLETE continues to take tangible steps toward advancing diversity, equity and inclusion by continuing to raise awareness, furthering intentional external relationships/partnerships, increasing supplier diversity, focus on underrepresented groups through grants/scholarships and other Company and employee giving.
Yellow Ribbon Program. ALLETE and its subsidiaries are dedicated to supporting veterans, military members and their families. An employee effort grew out of that spirit of commitment to veterans and led the state of Minnesota to designate ALLETE/Minnesota Power and ALLETE Clean Energy as Yellow Ribbon Companies. The mission of ALLETE’s Yellow Ribbon Program is to contribute to the Company’s unique culture by proactively recruiting and retaining the best and supporting an environment in which military-connected employees can thrive.
AVAILABILITY OF INFORMATION
ALLETE makes its SEC filings, including its annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and any amendments to those reports filed or furnished pursuant to Section 13(e) or 15(d) of the Securities Exchange Act of 1934, available free of charge on ALLETE’s website, www.allete.com, as soon as reasonably practicable after they are electronically filed with or furnished to the SEC.
ALLETE, Inc. 2022 Form 10-K
22
INFORMATION ABOUT OUR EXECUTIVE OFFICERS
As of February 16, 2023, these are the executive officers of ALLETE:
| | | | | |
| Executive Officers | Initial Effective Date |
| | |
| |
| |
| Bethany M. Owen, Age 57 | |
| Chair, President and Chief Executive Officer | May 11, 2021 |
| President and Chief Executive Officer | February 3, 2020 |
| President | January 31, 2019 |
| Senior Vice President and Chief Legal and Administrative Officer | November 26, 2016 |
| | |
| Patrick L. Cutshall, Age 57 | |
| Vice President and Corporate Treasurer | December 18, 2017 |
| |
| Nicole R. Johnson, Age 48 | |
| Vice President and President of ALLETE Clean Energy | August 22, 2022 |
| Vice President and Chief Administrative Officer | June 28, 2019 |
| |
| Steven W. Morris, Age 61 | |
| Senior Vice President and Chief Financial Officer | February 9, 2022 |
| Vice President and Chief Accounting Officer | October 28, 2021 |
| Vice President, Controller and Chief Accounting Officer | December 24, 2016 |
| |
| Joshua J. Skelton, Age 43 | |
| Vice President and Chief Operating Officer of Minnesota Power | August 22, 2022 |
| | |
| Margaret A. Thickens, Age 56 | |
| Vice President, Chief Legal Officer and Corporate Secretary | February 13, 2019 |
| |
| |
| |
| |
All of the executive officers have been employed by us for more than five years in executive or management positions. Prior to election to the position listed above, the following executives held other positions with the Company during the past five years.
Ms. Johnson was Vice President – Human Resources.
Mr. Skelton was Chief Operating Officer of Minnesota Power, Vice President Generation Operations and ALLETE Safety.
Ms. Thickens was General Counsel and Director of Compliance – ALLETE Clean Energy.
There are no family relationships between any of the executive officers. All officers and directors are elected or appointed annually.
The present term of office of the executive officers listed in the preceding table extends to the first meeting of our Board of Directors after the next annual meeting of shareholders. Both meetings are scheduled for May 9, 2023.
ALLETE, Inc. 2022 Form 10-K
23
Item 1A. Risk Factors
The risks and uncertainties discussed below could materially affect our business operations, financial position, results of operations and cash flows, and should be carefully considered by stakeholders. The risks and uncertainties in this section are not the only ones we face; additional risks and uncertainties that we are not presently aware of, or that we currently consider immaterial, may also affect our business operations, financial position, results of operations and cash flows. Accordingly, the risks described below should be carefully considered together with other information set forth in this report and in future reports that we file with the SEC.
Regulated Operations Risks
Our results of operations could be negatively impacted if our taconite, paper and pipeline customers experience an economic downturn, incur work stoppages, fail to compete effectively, experience decreased demand, fail to economically obtain raw materials, fail to renew or obtain necessary permits, or experience a decline in prices for their product.
Minnesota Power’s Large Power Customers (see Item 1. Business – Regulated Operations – Electric Sales / Customers) and Silver Bay Power accounted for 29 percent of our 2022 consolidated operating revenue (32 percent in 2021 and 29 percent in 2020) and 36 percent of Regulated Operations operating revenue (37 percent in 2021 and 34 percent in 2020). Minnesota Power’s taconite customers, which are currently owned by only two entities at the end of 2022, accounted for approximately 26 percent of consolidated operating revenue and 32 percent of Regulated Operations operating revenue in 2022. These customers are involved in cyclical industries that by their nature are adversely impacted by economic downturns and are subject to strong competition in the marketplace. The North American paper and pulp industry also faces declining demand due to the impact of electronic substitution for print and changing customer needs. As a result, certain paper and pulp customers have reduced their existing operations or idled facilities in recent years and have pursued or are pursuing product changes in response to declining demand. Additionally, the taconite industry could be impacted by changing technology in the steel industry such as the adoption of electric arc furnaces for steelmaking, which could result in declining demand for taconite and the electricity used during its production.
Minnesota Power also serves two pipeline customers that accounted for 2 percent of our 2022 consolidated operating revenue (2 percent in 2021 and in 2020) and 2 percent of Regulated Operations revenue in 2022 (2 percent in 2021 and 3 percent in 2020). These customers are involved in an industry that is seeing increased environmental pressure for construction of new or expanded pipeline infrastructure for the transportation of fossil fuels. Changes in regulatory rulings or permit proceedings could result in changes to operations of the pipeline network in our service territory.
Accordingly, if our industrial customers experience an economic downturn, incur a work stoppage (including strikes, lock-outs or other events), fail to compete effectively, experience decreased demand, fail to economically obtain raw materials, fail to renew or obtain necessary permits, or experience a decline in demand or prices for their product, there could be adverse effects on their operations and, consequently, this could have a negative impact on our results of operations as we are unable to remarket at similar prices the energy that would otherwise have been sold to such customers.
We may not be able to successfully implement our strategic objectives of growing load at our utilities if current or potential industrial or municipal customers are unable to successfully implement expansion plans, including the inability to obtain necessary governmental permits and approvals.
As part of our long-term strategy, we pursue new wholesale and retail loads in and around our service territories. Currently, there are several companies in northeastern Minnesota that are in the process of developing natural resource-based projects that represent long-term growth potential and load diversity for our Regulated Operations businesses. These projects may include construction of new facilities and restarts of old facilities, both of which require permitting and approvals to be obtained before the projects can be successfully implemented. If a project does not obtain any necessary governmental (including environmental) permits and approvals or if these customers are unable to successfully implement expansion plans, our long-term strategy and thus our results of operations could be adversely impacted.
ALLETE, Inc. 2022 Form 10-K
24
Item 1A. Risk Factors (Continued)
Regulated Operations Risks (Continued)
Our businesses, investments and customers are subject to an extensive legal and regulatory framework under federal and state laws as well as regulations imposed by other organizations that may have a negative impact on our business and results of operations.
Our businesses, investments and customers are subject to an extensive legal and regulatory framework imposed under federal and state law including regulations administered by the FERC, MPUC, MPCA, PSCW, NDPSC and EPA as well as regulations administered by other organizations including the NERC. These laws and regulations relate to allowed rates of return, capital structure, financings, rate and cost structure, acquisition and disposal of assets and facilities, construction and operation of generation, transmission and distribution facilities (including the ongoing maintenance and reliable operation of such facilities), recovery of purchased power costs and capital investments, approval of integrated resource plans and present or prospective wholesale and retail competition, renewable portfolio standards that require utilities to obtain specified percentages of electric supply from eligible renewable generation sources, among other things. Energy policy initiatives at the state or federal level could increase or accelerate renewable and carbon-free energy standards or incentives for distributed generation, municipal utility ownership, or local initiatives could introduce generation or distribution requirements that could change the current integrated utility model. (See Item 1. Business – Regulated Operations – Minnesota Legislation.) Our transmission systems and electric generation facilities are subject to the NERC mandatory reliability standards, including cybersecurity standards. Compliance with these standards may lead to increased operating costs and capital expenditures which are subject to regulatory approval for recovery. If it was determined that we were not in compliance with these mandatory reliability standards or other statutes, rules and orders, we could incur substantial monetary penalties and other sanctions, which could adversely affect our results of operations.
These laws and regulations significantly influence our operations and may affect our ability to recover costs from our customers. We are required to have numerous permits, licenses, approvals and certificates from the agencies and other organizations that regulate our business. We believe we have obtained the necessary permits, licenses, approvals and certificates for our existing operations and that our business is conducted in accordance with applicable laws; however, we are unable to predict the impact on our operating results from the future regulatory activities of any of these agencies and other organizations. Changes in regulations, timing of approvals, the adoption of new regulations or the expansion of jurisdiction by these agencies and other organizations could have an adverse impact on our business and results of operations.
Our ability to obtain rate adjustments to maintain reasonable rates of return depends upon regulatory action under applicable statutes and regulations, and we cannot provide assurance that rate adjustments will be obtained or reasonable authorized rates of return on capital will be earned. Minnesota Power and SWL&P, from time to time, file general rate cases with, or otherwise seek cost recovery authorization from, federal and state regulatory authorities. If Minnesota Power and SWL&P do not receive an adequate amount of rate relief in general rate cases, including if rates are reduced, if increased rates are not approved or recovered on a timely basis, if fuel adjustment clause recoveries or cost recovery for other items are not granted at the requested level, or costs are otherwise unable to be recovered through rates, we may experience an adverse impact on our financial position, results of operations and cash flows. We are unable to predict the impact on our business and results of operations from future legislation or regulatory activities of any of these agencies or organizations.
Our regulated operations present certain environmental risks that could adversely affect our financial position and results of operations, including effects of environmental laws and regulations, physical risks associated with climate change and initiatives designed to reduce the impact of GHG emissions.
We are subject to extensive environmental laws and regulations affecting many aspects of our past, present and future operations, including air quality, water quality and usage, waste management, reclamation, hazardous wastes, avian mortality and natural resources. These laws and regulations, or new laws and regulations that may be passed, can result in increased capital expenditures and increased operating and other costs as a result of compliance, remediation, containment and monitoring obligations, particularly with regard to laws relating to emissions, coal ash and water discharge at generating facilities.
These laws and regulations could restrict the output of some existing facilities, limit the use of some fuels in the production of electricity, require the installation of additional pollution control equipment, require participation in environmental emission allowance trading, and lead to other environmental considerations and costs, which could have an adverse impact on our business, operations and results of operations.
ALLETE, Inc. 2022 Form 10-K
25
Item 1A. Risk Factors (Continued)
Regulated Operations Risks (Continued)
These laws and regulations generally require us to obtain and comply with a wide variety of environmental licenses, permits, inspections and other approvals. Violations of these laws and regulations could expose us to regulatory and legal proceedings, disputes with, and legal challenges by, governmental authorities and private parties, as well as potential significant civil fines criminal penalties and other sanctions.
Existing environmental regulations may be revised and new environmental regulations may be adopted or become applicable to us. Revised or additional regulations which result in increased compliance costs or additional operating restrictions, particularly if those costs are not fully recoverable from customers, could have an adverse effect on our results of operations.
There is significant uncertainty regarding if and when new laws, regulations or administrative policies will be adopted to reduce or limit GHG and the impact any such laws or regulations would have on us. In 2022, our operating coal-fired generating facilities consisted of the 352 MW Boswell Unit 3 and the 468 MW Boswell Unit 4. (See Outlook – EnergyForward.) Any future limits on GHG emissions at the federal or state level, or action taken by regulators, before these facilities are retired or become coal-free may require us to incur significant capital expenditures and increases in operating costs, or could result in early closure of coal-fired generating facilities, stranded assets, an impairment of assets, denial of full recovery of decommissioning costs in excess of amounts previously collected, or otherwise adversely affect our results of operations, particularly if resulting expenditures and costs are not fully recoverable from customers.
Our regulated operations may be adversely impacted by the physical and financial risks associated with climate change. See Entity-wide Risks for additional discussion of risks related to GHG and climate change.
We cannot predict the amount or timing of all future expenditures related to environmental matters because of uncertainty as to applicable regulations or requirements. There is also uncertainty in quantifying liabilities under environmental laws that impose joint and several liability on all potentially responsible parties. Violations of certain environmental statutes, rules and regulations could expose ALLETE to third party disputes and potentially significant monetary penalties, as well as other sanctions for non‑compliance.
The operation and maintenance of our regulated electric generation, transmission and distribution facilities are subject to operational risks that could adversely affect our financial position, results of operations and cash flows.
The operation of generating facilities involves many risks, including start-up operational risks, breakdown or failure of facilities, the dependence on a specific fuel source, inadequate fuel supply, availability of fuel transportation, and the impact of unusual or adverse weather conditions or other natural events, as well as the risk of performance below expected levels of output or efficiency. A significant portion of our facilities contain older generating equipment, which, even if maintained in accordance with good engineering practices, may require significant capital expenditures to continue operating at peak efficiency. Generation, transmission and distribution facilities and equipment are also likely to require periodic upgrades and improvements due to changing environmental standards and technological advances. We could be subject to costs associated with any unexpected failure to produce or deliver power, including failure caused by breakdown, forced outage or limited availability of fuel or fuel transportation, as well as the repair of damage to facilities due to breakdown, storms, natural disasters, wars, sabotage, terrorist acts and other catastrophic events. This could also lead to requiring additional purchased power to meet requirements of serving our retail load, which for Minnesota Power is subject to recovery under the fuel adjustment clause. Should these costs be denied or are otherwise unable to be recovered, our financial position, results of operations and cash flows could be adversely impacted.
Our ability to successfully and timely complete capital repairs or improvements to existing regulated facilities or other capital projects is contingent upon many variables.
We expect to incur significant capital expenditures in making capital repairs or improvements to our existing electric generation and transmission facilities and in the development and construction of new electric generation and transmission facilities. Should any such efforts be unsuccessful, not completed in a timely manner or if there are increases in the costs for or limited availability of key materials, supplies, labor and services, we could be subject to additional costs or impairments, and projects may be delayed or canceled which could have an adverse impact on our financial position, results of operation and cash flows.
ALLETE, Inc. 2022 Form 10-K
26
Item 1A. Risk Factors (Continued)
Regulated Operations Risks (Continued)
Our regulated electric operations may not have access to adequate and reliable transmission and distribution facilities necessary to deliver electricity to our customers.
We depend on our own transmission and distribution facilities, as well as facilities owned by other utilities, to deliver the electricity sold to our customers, and to other energy suppliers. If transmission capacity is inadequate or transmission and distribution facilities we rely on are damaged, our ability to sell and deliver electricity may be limited. We may have to forgo sales or may have to buy more expensive wholesale electricity that is available in a capacity-constrained area. The ability to restore adequate capacity or repair damaged infrastructure may be impacted by the availability of key materials, supplies, labor and services, which if unavailable may prolong the impact of capacity constraints or damaged facilities. In addition, any infrastructure failure or damage that interrupts or impairs delivery of electricity to our customers could negatively impact the satisfaction of our customers, which could have an adverse impact on our business and results of operations.
The price of electricity may be volatile and fuel may be volatile and availability may be limited.
Volatility in market prices for electricity and volatility and limited availability of fuel could adversely impact our financial position and results of operations and may result from:
•severe or unexpected weather conditions and natural disasters;
•seasonality;
•changes in electricity usage;
•transmission or transportation constraints, inoperability or inefficiencies;
•availability of competitively priced alternative energy sources;
•changes in supply and demand for energy;
•changes in power production capacity;
•outages at our generating facilities or those of our competitors;
•availability of fuel and transportation of fuel;
•changes in production and storage levels of natural gas, lignite, coal, crude oil and refined products;
•wars, sabotage, terrorist acts or other catastrophic events; and
•federal, state, local and foreign energy, environmental, or other regulation and legislation.
Volatility in market prices for our fuel and purchase power costs impacts our sales to retail, municipal and Other Power Suppliers. Fluctuations in our fuel and purchased power costs related to our retail and municipal customers are passed on to customers through the fuel adjustment clause; however, our results of operations and cash flows may be adversely impacted if increased fuel adjustment clause rates are not approved or recovered on a timely basis, if cost recovery is not granted at the requested level, or costs are otherwise unable to be recovered through the fuel adjustment clause.
Wholesale prices for electricity have also declined in recent years primarily due to the extension of renewable tax credits and additional renewable generation commencing operations. If there are reductions in demand from current customers, we lose retail customers, or we lose municipal customers that do not renew existing contracts, we will market any available power to Other Power Suppliers in an effort to mitigate any earnings impact. Sales to Other Power Suppliers are sold at market-based prices into the MISO market on a daily basis or through bilateral agreements of various durations. Due to wholesale prices for electricity being below our rates for retail and municipal customers, we do not expect that our power marketing efforts would fully offset the reduction in earnings resulting from the lower demand from existing customers or the loss of customers. (See Item 1. Business – Regulated Operations – Electric Sales / Customers.)
ALLETE, Inc. 2022 Form 10-K
27
Item 1A. Risk Factors (Continued)
Regulated Operations Risks (Continued)
Demand for energy may decrease.
Our results of operations are impacted by the demand for energy in our service territories, our municipal customers and other power suppliers. There could be lower demand for energy due to a loss of customers as a result of economic conditions, customers constructing or installing their own generation facilities, higher costs and rates charged to customers, eligible municipal and other power suppliers choosing an alternative energy provider, or loss of service territory or franchises. Further, energy conservation and technological advances that increased energy efficiency may temporarily or permanently reduce the demand for energy products. In addition, we are impacted by state and federal regulations requiring mandatory conservation measures, which reduce the demand for energy products. Continuing technology improvements and regulatory developments may make customer and third party-owned generation technologies such as rooftop solar systems, WTGs, microturbines and battery storage systems more cost effective and feasible for certain customers. If customers utilize their own generation, demand for energy from us would decline. There may not be future economic growth opportunities that would enable us to replace the lost energy demand from these customers. Therefore, a decrease in demand for energy could adversely impact our financial position, results of operations and cash flows.
ALLETE Clean Energy / Corporate and Other Risks
The inability to successfully manage and grow our businesses could adversely affect our results of operations.
The Company's strategy includes adding customers, new geographies, and growth through acquisitions or project development with long-term PSAs in place for the output or to be sold upon completion. This strategy depends, in part, on the Company’s ability to successfully identify and evaluate acquisition or development opportunities and consummate acquisitions on acceptable terms. The Company may compete with other companies for these acquisition and development opportunities, which may increase the Company’s cost of making acquisitions and the Company may be unsuccessful in pursuing these acquisition opportunities. Other companies may be able to pay more for acquisitions and may be able to identify, evaluate, bid for and purchase a greater number of assets than the Company’s financial or human resources permit. New laws and regulations promoting renewable energy generation may result in increased competition. Our ALLETE Clean Energy business is experiencing return pressures from increased competition, and lower forward price curves, as a growing amount of investment capital is being directed into wind energy generation opportunities. In addition, current and potential new project developments at our businesses can be negatively affected by a lower ALLETE stock price, which may result in such projects not being accretive, or otherwise unable to satisfy our financial objectives criteria to proceed. Additionally, tax law changes may adversely impact the economic characteristics of potential acquisitions or investments. If the Company is unable to execute its strategy of growth through acquisitions, project development for others, or the addition of new customers and geographies, it may impede our long-term objectives and business strategy.
Acquisitions are subject to uncertainties. If we are unable to successfully integrate and manage the acquisition of New Energy, or future acquisitions and strategic investments, this could have an adverse impact on our results of operations. Our actual results may also differ from our expectations due to factors such as the ability to obtain timely regulatory or governmental approvals, integration and operational issues and the ability to retain management and other key personnel.
Our results of operations could be adversely affected by changes in governmental incentives or policies that support renewable energy or changes in taxes, tariffs, duties or other assessments on renewable energy or the equipment necessary to generate and deliver it.
Any reductions or modifications to, or the elimination of, governmental incentives or policies that support renewable energy, or the imposition of additional or increased sourcing of components subject to taxes, tariffs, duties or other assessments on renewable energy or the equipment necessary to generate and deliver it, could result in, among other items, the lack of a satisfactory market for the development or financing of new renewable energy projects and reduced project returns on current or future projects.
ALLETE, Inc. 2022 Form 10-K
28
Item 1A. Risk Factors (Continued)
ALLETE Clean Energy / Corporate and Other Risks (Continued)
The U.S. government currently imposes antidumping and countervailing duties on certain imported photovoltaic (PV) cells and modules from China and Taiwan. Such duties can change over time pursuant to annual reviews conducted by the U.S. Department of Commerce (DOC). In March 2022, the U.S. DOC launched an investigation into alleged circumvention of these duties by imports of certain PV cells and modules assembled and completed in Cambodia, Malaysia, Thailand, and Vietnam. In June 2022, the U.S. President declared an emergency with respect to threats to electricity generation capacity and authorized the U.S. Secretary of Commerce to consider permitting the importation of certain PV products from those four countries free of antidumping and countervailing duties for 24 months, or until the emergency has terminated. The U.S. DOC has issued final regulations designed to implement that moratorium in the event that it finds circumvention in its ongoing inquiries. We cannot predict what further actions the U.S. DOC will take with respect to these circumvention inquiries. Our operating results could be adversely impacted if the U.S. DOC makes circumvention determinations that result in duties assessed on future purchases made by our businesses after the moratorium ends.
The generation of electricity from wind and solar energy facilities depends heavily on suitable meteorological conditions.
Although our electric generation facilities are located in diverse geographic regions to reduce the potential impact that may be caused by unfavorable weather in a particular region, suitable meteorological conditions are variable and difficult to predict. If wind or solar conditions are unfavorable or meteorological conditions are unsuitable, electricity generation and revenue from wind and solar energy facilities may be substantially below our expectations. The electricity produced, production tax credits received, and revenues generated by a wind or solar energy facility are highly dependent on suitable wind conditions and associated weather conditions, which are variable and beyond our control. We base our decisions about which wind and solar projects to build or acquire as well as our electricity generation estimates, in part, on the findings of long-term wind and other meteorological studies conducted on the project site and its region; however, the unpredictable nature of wind and solar conditions, weather and meteorological conditions can result in material deviations from these studies and our expectations. Furthermore, components of our systems could be damaged by severe weather, such as hailstorms, lightning or tornadoes. In addition, replacement and spare parts for key components may be difficult or costly to acquire or may be unavailable. Unfavorable wind and solar conditions, weather or changes to meteorological patterns could impair the effectiveness of our electric generation facility assets, reduce their output beneath their rated capacity or require shutdown of key equipment, impeding operation of our wind energy facilities or lead to an impairment of assets.
The construction, operation and maintenance of our electric generation facilities or investment in facilities are subject to operational risks that could adversely affect our financial position, results of operations and cash flows.
The construction and operation of generating facilities involves many risks, including the performance by key contracted suppliers and maintenance providers; increases in the costs for or limited availability of key materials, supplies, labor and services; start-up operations risks; breakdown or failure of facilities; curtailment of facilities by counterparties; the dependence on the availability of wind resources; or the impact of unusual, adverse weather conditions or other natural events, as well as the risk of performance below expected levels of output or efficiency. Some of our facilities contain older generating equipment, which even if maintained in accordance with good engineering practices, may require significant capital expenditures to continue operating at peak efficiency. We could be subject to costs associated with any unexpected failure to produce and deliver power, including failure caused by breakdown or forced outage, as well as the repair of damage to facilities due to storms, natural disasters, wars, sabotage, terrorist acts and other catastrophic events.
The price of electricity may be volatile, which may impact results of operations at ALLETE Clean Energy wind energy facilities under contracts with customer and industrial (C&I) customers.
Unusual, adverse weather conditions or other natural events and different settlement prices between hub and node can cause volatility in market prices for electricity and adversely affect our financial position, results of operations and cash flows. ALLETE Clean Energy’s power sales agreements with C&I customers at its Diamond Spring and Caddo wind energy facilities are contracts for differences where power is delivered to the market, a fixed price is paid by the customers to ALLETE Clean Energy, and differences between the market price and the fixed price are paid to or received from the customers. Certain contracts also settle with the market at the hub price whereas ALLETE Clean Energy settles with the customer at the node price which can vary significantly based on multiple factors. These settlement provisions can result in an adverse impact on our financial position, results of operations and cash flows when market prices are volatile.
ALLETE, Inc. 2022 Form 10-K
29
Item 1A. Risk Factors (Continued)
ALLETE Clean Energy / Corporate and Other Risks (Continued)
As contracts with counterparties expire, we may not be able to replace them with agreements on similar terms or divest the related assets at a profit.
ALLETE Clean Energy is party to PSAs that expire in various years between 2024 and 2039. These PSA expirations are prior to the end of the estimated useful lives of the respective wind energy facilities. If, for any reason, ALLETE Clean Energy is unable to enter into new agreements with existing or new counterparties on similar terms once the current agreements expire, sell energy in the wholesale market resulting in similar revenue, or enter into a contract to sell the facility at a profit, our financial position, results of operations and cash flows could be adversely affected, which includes potential impairment of property, plant and equipment.
Counterparties to turbine and other generation supply, service and maintenance, or power sale agreements may not fulfill their obligations.
Our businesses are party to turbine and other generation supply agreements, service and maintenance agreements, and PSAs under various durations with a limited number of creditworthy counterparties. If, for any reason, any of the counterparties under these agreements do not fulfill their related contractual obligations, and we are unable to mitigate non-performance by a key supplier or maintenance provider or remarket PSA energy resulting in similar revenue, our financial position, results of operations and cash flows could be adversely affected.
ALLETE has a significant amount of goodwill. A determination that goodwill has been impaired could result in a significant non-cash charge to earnings.
We had approximately $155 million of goodwill recorded on our Consolidated Balance Sheet as of December 31, 2022 related to New Energy. If we change our business strategy, fail to deliver on our projected results or if market or other conditions adversely affect the operations of New Energy, we may be required to record an impairment charge. Declines in projected operating cash flows at New Energy could also result in an impairment charge. An impairment charge would result in a non-cash charge to earnings that could have an adverse effect on our results of operations.
BNI Energy may be adversely impacted by its exposure to customer concentration, and environmental laws and regulations.
BNI Energy sells lignite coal to two electric generating cooperatives, Minnkota Power and Square Butte, and could be adversely impacted if these customers were unable or unwilling to fulfill their related contractual obligations, or change the way in which they operate their generating facilities. In addition, BNI Energy and its customers may be adversely impacted by existing or new environmental laws and regulations which could have an adverse effect on our financial position, results of operations and cash flows. In addition, insurance companies have decreased the available coverage for policy holders in the mining industry, impacting the availability of coverage, and leading to higher deductibles and premiums.
Real estate market conditions where our legacy Florida real estate investment is located may deteriorate.
The Company’s strategy related to the real estate assets of ALLETE Properties incorporates the possibility of a bulk sale of its entire portfolio, in addition to sales over time, however, adverse market conditions could impact the timing of land sales, which could result in little to no sales, while still incurring operating expenses such as community development district assessments and property taxes, resulting in net operating losses at ALLETE Properties. Furthermore, weak market conditions could put the properties at risk for an impairment charge. An impairment charge would result in a non-cash charge to earnings that could have an adverse effect on our results of operations.
Entity-wide Risks
We could be materially adversely affected by health epidemics, pandemics and other outbreaks.
Health epidemics, pandemics and other outbreaks, as well as the related federal and state government responses, can have widespread impacts on the economy and on our employees, customers, contractors and suppliers, such as those experienced from the ongoing COVID-19 pandemic. There may be uncertainty regarding the length of time an epidemic, pandemic or other outbreak will last, how they will evolve, or the extent and duration of any measures attempted to try and contain them.
ALLETE, Inc. 2022 Form 10-K
30
Item 1A. Risk Factors (Continued)
Entity-wide Risks (Continued)
A disruption of economic activity or an extended disruption of economic activity may lead to adverse impacts on our taconite, paper, pulp and secondary wood products, and pipeline customers’ operations including reduced production or the temporary idling or indefinite shutdown of facilities, which would result in lower sales and revenue from these customers. A disruption in capital markets could lead to increased borrowing costs or adversely impact our ability to access capital markets or other financing sources, which would adversely affect our ability to maintain our businesses or to implement our business plans. An epidemic, pandemic or other outbreak may also result in a disruption to our supply chains which could adversely impact our operations and capital projects resulting in project and operational delays, project cancellations, lower returns on projects and cost increases.
Despite any efforts made to mitigate the impacts on the Company of an epidemic, pandemic or other outbreak, their ultimate impact also depends on factors beyond our control, including their duration and severity as well as governmental and third-party actions taken to contain their spread and mitigate their public health effects. As a result, we cannot predict the ultimate impact of an epidemic, pandemic or other outbreak, such as the ongoing COVID-19 pandemic and whether it will have a material impact on our liquidity, financial position, results of operations and cash flows.
We rely on access to financing sources and capital markets. If we do not have access to capital on acceptable terms or are unable to obtain capital when needed, our ability to execute our business plans, make capital expenditures or pursue other strategic actions that we may otherwise rely on for future growth would be adversely affected.
We rely on access to financing sources and the capital markets, on acceptable terms and at reasonable costs, as sources of liquidity for capital requirements not satisfied by our cash flows from operations. Rising interest rates, inflation and market disruptions or a downgrade of our credit ratings may increase the cost of borrowing or adversely affect our ability to access and finance in the capital markets or to access other financing sources such as tax equity financing. Such disruptions or causes of a downgrade could include but are not limited to: weakening of the Company’s cash flow metrics; a loss of, or a reduction in sales to, our taconite, paper and pipeline customers if we are unable to offset the related lost margins; weaker operating performance; adverse regulatory outcomes; disproportionate increase in the contribution to net income from ALLETE Clean Energy and our Corporate and Other businesses as compared to that from our Regulated Operations; deteriorating economic or capital market conditions; or volatility in commodity prices.
If we are not able to access capital on acceptable terms in sufficient amounts and when needed, or at all, the ability to maintain our businesses or to implement our business plans would be adversely affected. This would include our ability to make the significant capital expenditures planned in order to achieve Minnesota Power’s clean-energy transition plans. (See Item 7. Capital Requirements.)
A deterioration in general economic conditions, an inflationary environment or supply chain disruptions may have adverse impacts on our financial position, results of operations and cash flows.
If economic conditions deteriorate, we experience an inflationary environment or supply chains are disrupted on a national, regional or global level, it may have a negative impact on our customers and the Company’s financial position, results of operations and cash flows. This impact may include volatility and unpredictability in the demand for the products and services offered by our businesses, the loss of existing customers, tempered growth strategies, customer production cutbacks, customer bankruptcies and increases in costs for or limited availability of key materials, supplies, labor and services for our operations and capital projects. An uncertain economy could also adversely affect expenses including pension costs, interest costs, and uncollectible accounts, or lead to reductions in the value of certain real estate and other investments.
Our utility infrastructure and generating facilities, ongoing and future capital and development projects, and other operations require components, supplies, materials, labor and services sourced from suppliers or providers who, in turn, may source components from their suppliers. A shortage of key components, supplies, materials, labor or services in which an alternative supplier or provider is not identified could significantly impact project plans or our operations. Such impacts could include project delays, including potential for project cancellation, lower project returns, increased costs or the inability to provide service to customers, which could adversely impact our results of operations, financial condition or cash flows.
ALLETE, Inc. 2022 Form 10-K
31
Item 1A. Risk Factors (Continued)
Entity-wide Risks (Continued)
Our businesses, investments and customers are subject to extensive state and federal legislation and regulation, compliance with which could have an adverse effect on our businesses.
Our businesses, investments and customers are subject to, and affected by, extensive state and federal legislation and regulation. If it was determined that our businesses failed to comply with applicable laws and regulations, we could become subject to fines or penalties or be required to implement additional compliance measures or actions, the cost of which could be material. Adoption of new laws, rules, regulations, principles, or practices by federal and state agencies, or changes to or a failure to comply with current laws, rules, regulations, principles, or practices and their interpretations, could have an adverse effect on our financial position, results of operations and cash flows.
The inability to attract and retain a qualified workforce including, but not limited to, executive officers, key employees and employees with specialized skills, could have an adverse effect on our operations.
The success of our business heavily depends on the leadership of our executive officers and key employees to implement our business strategy. The inability to maintain a qualified workforce, including, but not limited to, executive officers, key employees and employees with specialized skills, may negatively affect our ability to service our existing or new customers, or successfully manage our business or achieve our business objectives. Personnel costs may increase due to competitive pressures, inflation or terms of collective bargaining agreements with union employees.
Market performance and other changes could decrease the value of pension and other postretirement benefit plan assets, which may result in significant additional funding requirements and increased annual expenses.
The performance of the capital markets impacts the values of the assets that are held in trust to satisfy future obligations under our pension and other postretirement benefit plans. We have significant obligations to these plans and the trusts hold significant assets. These assets are subject to market fluctuations and will yield uncertain returns, which may fall below our projected rates of return. A decline in the market value of the pension and other postretirement benefit plan assets would increase the funding requirements under our benefit plans if asset returns do not recover. Additionally, our pension and other postretirement benefit plan liabilities are sensitive to changes in interest rates. As interest rates decrease, the liabilities increase, potentially increasing benefit expense and funding requirements. Our pension and other postretirement benefit plan costs are generally recoverable in our electric rates as allowed by our regulators or through our cost-plus fixed fee coal supply agreements at BNI Energy; however, there is no certainty that regulators will continue to allow recovery of these rising costs in the future.
We are exposed to significant reputational risk.
The Company could suffer negative impacts to its reputation as a result of operational incidents, violations of corporate compliance policies, regulatory violations, operations that produce or enable the production of GHG emissions or other events which may result in negative customer perception, increased regulatory oversight, and negative consequences to our credit ratings and ability to access capital, each of which could have an adverse effect on our financial position, results of operations and cash flows.
We are subject to physical and financial risks associated with climate change and other catastrophic events, such as natural disasters and acts of war.
Catastrophic events at or near Company facilities and equipment on which the Company depends upon or that otherwise impact the Company such as fires, wildfires, including the impact to Company facilities and operations or potential liability if caused by Company equipment, earthquakes, explosions, and floods, severe weather, such as ice storms, hailstorms, or tornadoes or similar occurrences, as well as acts of war, could adversely affect the Company’s facilities, operations, financial position, results of operations and cash flows. Although the Company has contingency plans and employs crisis management to respond and recover operations in the event of a severe disruption resulting from a catastrophic event, these measures may not be successful. Furthermore, despite these measures, if a catastrophic event were to occur, our financial position, results of operations and cash flows could be adversely affected.
ALLETE, Inc. 2022 Form 10-K
32
Item 1A. Risk Factors (Continued)
Entity-wide Risks (Continued)
The scientific community generally accepts that emissions of GHG are linked to global climate change. Physical risks of climate change, such as more frequent, longer duration or more extreme weather events, changes in temperature and precipitation patterns, increased risk of wildfires, changes to ground and surface water availability, and other related phenomena, could affect some, or all, of our operations. Severe weather or other natural disasters could be destructive, which could result in increased costs or limit the availability of key materials, supplies, labor and services used in our operations or to respond to damaged facilities. An extreme weather event can also directly affect our capital assets, causing disruption in service to customers due to facility outages, downed wires and poles or damage to other operating equipment.
Climate-related risks that could adversely affect our financial position and results of operations include effects of environmental- or economic-based laws, regulations, incentives or initiatives designed to reduce the quantity or impact of GHG emissions, the ability of our regulated businesses to obtain rate adjustments to recover costs and investments to implement clean-energy transition plans, or disruptions to the economy or energy markets caused by climate change. This includes the risk of laws or regulations that create mandates that do not allow for a transition that protects the safety, reliability or affordability of energy for our customers, are implemented before cost-effective technology is developed and regulatory policy is established, or require the electric sector to decarbonize faster than other sectors and ahead of our current goal to deliver 100 percent carbon-free energy to customers by 2050. Additionally, restrictions on land use, wildlife impacts, and other environmental regulations could affect the siting, construction and operation of new or existing generation and transmission facilities needed to transition to lower-carbon generation sources.
These all have the potential to adversely affect our business and operations.
We are vulnerable to acts of terrorism or cybersecurity attacks.
Our operations may be targets of terrorist activities or cybersecurity attacks, which could disrupt our ability to provide utility service at our regulated utilities, develop or operate our renewable energy projects at ALLETE Clean Energy, or operate our other businesses. The impacts may also impair the fulfillment of critical business functions, negatively impact our reputation, subject us to litigation or increased regulation, or compromise sensitive, confidential and other data.
There have been cybersecurity attacks on U.S. energy infrastructure in the past and there may be such attacks in the future. Our generation, transmission and distribution facilities, information technology systems and other infrastructure facilities and systems could be direct targets of, or otherwise be materially adversely affected by such activities. Hacking, computer viruses, terrorism, theft and sabotage could impact our systems and facilities, or those of third parties on which we rely, which may disrupt our operations.
Our businesses require the continued operation of sophisticated custom-developed, purchased, and leased information technology systems and network infrastructure as well as the collection and retention of personally identifiable information of our customers, shareholders and employees. Although we maintain security measures designed to prevent cybersecurity incidents and protect our information technology and control systems, network infrastructure and other assets, our technology systems, or those of third parties on which we rely, may be vulnerable to disability, failures or unauthorized access due to hacking, viruses, acts of war or terrorism as well as other causes. If those technology systems fail or are breached and not recovered in a timely manner, we may be unable to perform critical business functions including effectively maintaining certain internal controls over financial reporting, our reputation may be negatively impacted, we may become subject to litigation or increased regulation, and sensitive, confidential and other data could be compromised. If our business were impacted by terrorist activities or cybersecurity attacks, such impacts could have an adverse effect on our financial position, results of operations and cash flows.
We maintain insurance against some, but not all, of the risks and uncertainties we face.
We maintain insurance against some, but not all, of the risks and uncertainties we face. The occurrence of these risks and uncertainties, if not fully covered by insurance, could have a material effect on our financial position, results of operations and cash flows.
ALLETE, Inc. 2022 Form 10-K
33
Item 1A. Risk Factors (Continued)
Entity-wide Risks (Continued)
Government challenges to our tax positions, as well as tax law changes and the inherent difficulty in quantifying potential tax effects of our operations and business decisions, could adversely affect our results of operations and liquidity.
We are required to make judgments regarding the potential tax effects of various financial transactions and our ongoing operations in order to estimate our obligations to taxing authorities. The obligations, which include income taxes and taxes other than income taxes, involve complex matters that ultimately could be litigated. We also estimate our ability to use tax benefits, including those in the form of carryforwards and tax credits that are recorded as deferred tax assets on our Consolidated Balance Sheet. A disallowance of some or all of these tax benefits could have an adverse impact on our financial position, results of operations and cash flows.
We are currently utilizing, and plan to utilize in the future, our carryforwards and tax credits to reduce our income tax obligations. If we cannot generate enough taxable income in the future to utilize all of our carryforwards and tax credits before they expire, we may incur adverse charges to earnings.
If federal or state tax authorities deny any deductions or tax credits, negatively change existing tax laws or policies, or fail to extend or renew policies beneficial to the Company, such as those for renewable energy production tax credits, our financial position, results of operations and cash flows may be adversely impacted.
Item 1B. Unresolved Staff Comments
None.
Item 2. Properties
A discussion of our properties is included in Item 1. Business and is incorporated by reference herein.
Item 3. Legal Proceedings
Discussions of material regulatory and environmental proceedings are included in Note 4. Regulatory Matters and Note 9. Commitments, Guarantees and Contingencies, and are incorporated by reference herein.
We are involved in litigation arising in the normal course of business. Also in the normal course of business, we are involved in tax, regulatory and other governmental audits, inspections, investigations and other proceedings that involve state and federal taxes, safety, and compliance with regulations, rate base and cost of service issues, among other things. We do not expect the outcome of these matters to have a material effect on our financial position, results of operations or cash flows.
Item 4. Mine Safety Disclosures
The Dodd-Frank Wall Street Reform and Consumer Protection Act (Dodd-Frank Act) requires issuers to include in periodic reports filed with the SEC certain information relating to citations or orders for violations of standards under the Federal Mine Safety and Health Act of 1977 (Mine Safety Act). Information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Act and this Item are included in Exhibit 95 to this Form 10-K.
ALLETE, Inc. 2022 Form 10-K
34
Part II
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Our common stock is listed on the NYSE under the symbol ALE. We have paid dividends, without interruption, on our common stock since 1948. A quarterly dividend of $0.6775 per share on our common stock is payable on March 1, 2023, to the shareholders of record on February 15, 2023. The timing and amount of future dividends will depend upon earnings, cash requirements, the financial condition of the Company, applicable government regulations and other factors deemed relevant by the ALLETE Board of Directors. As of February 1, 2023, there were approximately 20,000 common stock shareholders of record.
Performance Graph.
The following graph compares ALLETE’s cumulative Total Shareholder Return on its common stock with the cumulative return of the S&P 500 Index and the Philadelphia Utility Index. The S&P 500 Index is a capitalization-weighted index of 500 stocks designed to measure performance of the broad domestic economy through changes in the aggregate market value of 500 stocks representing all major industries. Because this composite index has a broad industry base, its performance may not closely track that of a composite index comprised solely of electric utilities. The Philadelphia Utility Index is a capitalization-weighted index of 20 utility companies involved in the generation of electricity.
The calculations assume a $100 investment on December 31, 2017, and reinvestment of dividends.
| | | | | | | | | | | | | | | | | | | | |
| 2017 | 2018 | 2019 | 2020 | 2021 | 2022 |
| ALLETE | $100 | $106 | $116 | $92 | $102 | $104 |
| S&P 500 Index | $100 | $96 | $126 | $149 | $192 | $157 |
| Philadelphia Utility Index | $100 | $104 | $131 | $135 | $159 | $160 |
ALLETE, Inc. 2022 Form 10-K
35
Item 6. [Reserved]
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion should be read in conjunction with our Consolidated Financial Statements and notes to those statements and the other financial information appearing elsewhere in this report. In addition to historical information, the following discussion and other parts of this Form 10-K contain forward-looking information that involves risks and uncertainties. Readers are cautioned that forward-looking statements should be read in conjunction with our disclosures in this Form 10-K under the headings: “Forward‑Looking Statements” located on page 6 and “Risk Factors” located in Item 1A. The risks and uncertainties described in this Form 10-K are not the only risks facing our Company. Additional risks and uncertainties that we are not presently aware of, or that we currently consider immaterial, may also affect our business operations. Our business, financial condition or results of operations could suffer if the risks are realized.
Overview
Basis of Presentation. We present two reportable segments: Regulated Operations and ALLETE Clean Energy. Our segments were determined in accordance with the guidance on segment reporting. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment.
Regulated Operations includes our regulated utilities, Minnesota Power and SWL&P, as well as our investment in ATC, a Wisconsin-based regulated utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. Minnesota Power provides regulated utility electric service in northeastern Minnesota to approximately 150,000 retail customers. Minnesota Power also has 14 non-affiliated municipal customers in Minnesota. SWL&P is a Wisconsin utility and a wholesale customer of Minnesota Power. SWL&P provides regulated utility electric, natural gas and water service in northwestern Wisconsin to approximately 15,000 electric customers, 13,000 natural gas customers and 10,000 water customers. Our regulated utility operations include retail and wholesale activities under the jurisdiction of state and federal regulatory authorities. (See Note 4. Regulatory Matters.)
ALLETE Clean Energy focuses on developing, acquiring, and operating clean and renewable energy projects. ALLETE Clean Energy currently owns and operates, in seven states, more than 1,200 MW of nameplate capacity wind energy generation with a majority contracted under PSAs of various durations. In addition, ALLETE Clean Energy also engages in the development of wind energy facilities to operate under long-term PSAs or for sale to others upon completion. ALLETE Clean Energy currently has approximately 100 MW of wind energy facilities under contract to be sold to others.
Corporate and Other is comprised of New Energy, a renewable development company; our investment in Nobles 2, an entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota; South Shore Energy, our non-rate regulated, Wisconsin subsidiary developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility; BNI Energy, our coal mining operations in North Dakota; ALLETE Properties, our legacy Florida real estate investment; other business development and corporate expenditures; unallocated interest expense; a small amount of non-rate base generation; land holdings in Minnesota; and earnings on cash and investments.
ALLETE is incorporated under the laws of Minnesota. Our corporate headquarters are in Duluth, Minnesota. Statistical information is presented as of December 31, 2022, unless otherwise indicated. All subsidiaries are wholly-owned unless otherwise specifically indicated. References in this report to “we,” “us” and “our” are to ALLETE and its subsidiaries, collectively.
ALLETE, Inc. 2022 Form 10-K
36
2022 Financial Overview
The following net income discussion summarizes a comparison of the year ended December 31, 2022 to the year ended December 31, 2021.
Net income attributable to ALLETE in 2022 was $189.3 million, or $3.38 per diluted share, compared to $169.2 million, or $3.23 per diluted share, in 2021. Net income in 2022 included higher earnings at Minnesota Power resulting from the implementation of interim rates on January 1, 2022, net of interim rate reserves, and also included net income of $7.8 million from New Energy, which was acquired in April 2022. These increases were partially offset by lower earnings from ALLETE Clean Energy reflecting challenges under the Caddo and Diamond Spring wind energy facilities’ power sales agreements and additional losses related to the sale of the Northern Wind project. Net income in 2021 included South Shore Energy’s sale of a portion of its interest in NTEC to Basin Electric Cooperative and the resulting recognition of an approximately $8.5 million after-tax gain, or $0.16 per share, related to prior development costs and risks incurred. Net income in 2021 also included an approximately $5 million after-tax, or $0.10 per share, negative impact related to ALLETE Clean Energy’s Diamond Spring wind energy facility due to an extreme winter storm event in the southwest United States in February 2021. Earnings per share dilution in 2022 was $0.23 due to additional shares of common stock outstanding as of December 31, 2022.
Regulated Operations net income attributable to ALLETE was $149.9 million in 2022, compared to $129.1 million in 2021. Net income at Minnesota Power was higher than 2021 primarily due to the implementation of interim rates on January 1, 2022, net of interim rate reserves. This increase was partially offset by higher costs under a PPA with Manitoba Hydro, higher operating and maintenance expense, and lower kWh sales to industrial customers. Our after-tax equity earnings in ATC were lower than 2021 primarily due to period over period changes in ATC’s estimate of a refund liability related to the appeals court decision on MISO return on equity complaints. (See Note 6. Equity Investments.)
ALLETE Clean Energy net income attributable to ALLETE was $16.3 million in 2022 compared to $26.3 million in 2021. Net income in 2022 reflected challenges under the Caddo and Diamond Spring wind energy facilities’ power sales agreements resulting from extreme market volatility and transmission congestion in the Southwest Power Pool. Net income in 2022 also included additional losses related to the sale of the Northern Wind project. Net income in 2021 included an approximately $5 million after-tax negative impact related to ALLETE Clean Energy’s Diamond Spring wind energy facility due to an extreme winter storm event in the southwest United States in February 2021.
Corporate and Other net income attributable to ALLETE was $23.1 million in 2022 compared to $13.8 million in 2021. Net income in 2022 reflects net income from New Energy of $7.8 million, which included a $8.3 million after-tax expense as a result of purchase price accounting related to projects under development at the time of acquisition. Net income in 2022 also reflects higher earnings from our investment in Nobles 2 due to higher wind resources in 2022, higher land sales at ALLETE Properties, earnings from Minnesota solar projects placed into service in 2022 and lower income taxes. These increases were partially offset by transaction costs of $2.7 million after-tax related to the acquisition of New Energy, and higher other expenses compared to 2021. Net income in 2021 included South Shore Energy’s sale of a portion of its interest in NTEC to Basin which resulted in the recognition of an approximately $8.5 million after-tax gain related to prior development costs and risks incurred.
ALLETE, Inc. 2022 Form 10-K
37
2022 Compared to 2021
(See Note 14. Business Segments for financial results by segment.)
Regulated Operations
| | | | | | | | |
| Year Ended December 31 | 2022 | 2021 |
| Millions | | |
| Operating Revenue – Utility | $1,259.3 | | $1,227.9 | |
| Fuel, Purchased Power and Gas – Utility | 545.5 | | 562.4 | |
| Transmission Services – Utility | 76.7 | | 75.3 | |
| | |
| Operating and Maintenance | 239.3 | | 216.0 | |
| Depreciation and Amortization | 171.9 | | 170.7 | |
| Taxes Other than Income Taxes | 57.4 | | 60.9 | |
| Operating Income | 168.5 | | 142.6 | |
| Interest Expense | (58.1) | | (57.3) | |
| Equity Earnings | 19.3 | | 21.3 | |
| Other Income | 9.8 | | 5.9 | |
| Income Before Income Taxes | 139.5 | | 112.5 | |
| Income Tax Benefit | (10.4) | | (16.6) | |
| | |
| | |
| Net Income Attributable to ALLETE | $149.9 | $129.1 | |
Operating Revenue – Utility increased $31.4 million from 2021 primarily due to the implementation of interim rates at Minnesota Power on January 1, 2022, as well as increased recoveries under the Minnesota conservation improvement program and higher gas sales. These increases were partially offset by lower revenue from kWh sales and lower fuel adjustment clause recoveries.
Interim retail rate revenue of $85.5 million was collected in 2022, which was partially offset by an interim rate refund reserve of approximately $18 million due to the regulatory outcome of the MPUC’s decision in Minnesota Power’s 2022 general rate case. In addition, Minnesota Power recorded a charge of approximately $8 million pre-tax to write off the deferred portion of residential customer interim rates. Minnesota Power also recorded additional revenue of approximately $9 million pre-tax for an increase in expected recoveries under its cost recovery riders. (See Note 4. Regulatory Matters.)
Conservation improvement program recoveries increased $5.9 million from 2021 primarily due to an increase in related expenditures. (See Operating Expenses - Operating and Maintenance.)
Gas sales at SWL&P increased $4.6 million as a result of colder weather and higher gas prices in 2022 compared to 2021. (See Fuel, Purchased Power and Gas – Utility.)
Lower kWh sales reduced revenue $27.4 million from 2021 reflecting lower sales to industrial customers and other power suppliers, partially offset by higher sales to residential and commercial customers as well as higher pricing on sales to other power suppliers. Sales to residential and commercial customers increased from 2021 primarily due to colder weather in 2022 compared to 2021. Sales to industrial customers decreased primarily due to lower sales to taconite customers resulting from less taconite production in 2022 compared to 2021, reflecting Cliffs’ Northshore mine being temporarily idled in 2022. (See Outlook - Customers - Northshore Mining.) Sales to other power suppliers, which are sold at market-based prices into the MISO market on a daily basis or through PSAs of various durations, decreased in 2022 compared to 2021 primarily due to additional kWh sales made in 2021 to mitigate the uncertainty of customers’ energy needs and potential load loss due to the COVID-19 pandemic.
ALLETE, Inc. 2022 Form 10-K
38
2022 Compared to 2021 (Continued)
Regulated Operations (Continued)
| | | | | | | | | | | | | | |
Kilowatt-hours Sold | 2022 | 2021 | Quantity
Variance | %
Variance |
| Millions | | | | |
| Regulated Utility | | | | |
| Retail and Municipal | | | | |
| Residential | 1,148 | | 1,135 | | 13 | | 1.1 | |
| Commercial | 1,359 | | 1,359 | | — | | — | |
| Industrial | 6,745 | | 7,196 | | (451) | | (6.3) | |
| Municipal | 540 | | 590 | | (50) | | (8.5) | |
| Total Retail and Municipal | 9,792 | | 10,280 | | (488) | | (4.7) | |
| Other Power Suppliers | 3,149 | | 5,102 | | (1,953) | | (38.3) | |
| Total Regulated Utility Kilowatt-hours Sold | 12,941 | | 15,382 | | (2,441) | | (15.9) | |
Revenue from electric sales to taconite customers accounted for 32 percent of regulated operating revenue in 2022 (33 percent in 2021). Revenue from electric sales to paper, pulp and secondary wood product customers accounted for 5 percent of regulated operating revenue in 2022 (5 percent in 2021). Revenue from electric sales to pipelines and other industrial customers accounted for 10 percent of regulated operating revenue in 2022 (9 percent in 2021).
Fuel adjustment clause revenue decreased $24.1 million primarily due to lower kWh sales, partially offset by higher fuel and purchased power costs attributable to retail and municipal customers. (See Fuel, Purchased Power and Gas – Utility.) Fuel adjustment clause revenue in 2021 also reflected a $5 million charge recorded in 2021 resulting from the MPUC’s decision to order refunds in Minnesota Power’s fuel adjustment clause filing covering the period July 2018 through December 2019. (See Note 4. Regulatory Matters.)
Operating Expenses increased $5.5 million from 2021.
Operating and Maintenance expense increased $23.3 million, or 11 percent, from 2021 primarily due to higher conservation improvement program expenses, professional services and materials purchased for generation facilities, labor expenses and higher vegetation management expenses. These increases were partially offset by lower pension and other postretirement benefit expenses. In addition, 2022 included rate case-related expenses for Minnesota Power’s rate case. (See Note 4. Regulatory Matters.)
Transmission Services – Utility expense increased $1.4 million, or 2 percent, from 2021 primarily due to higher MISO-related expense.
Depreciation and Amortization expense increased $1.2 million, or 1 percent, from 2021 primarily due to a higher plant in service balance in 2022.
Fuel, Purchased Power and Gas – Utility expense decreased $16.9 million, or 3 percent, from 2021 primarily due to lower energy purchases due to lower kWh sales, partially offset by higher purchased power prices and fuel prices. Fuel and purchased power expense related to our retail and municipal customers is recovered through the fuel adjustment clause.
Taxes Other than Income Taxes decreased $3.5 million, or 6 percent, from 2021 primarily due to lower property tax expense resulting from an updated estimate of taxable market values and rates in 2022.
Equity Earnings decreased $2.0 million from, or 9 percent, 2021 primarily due to period over period changes in ATC’s estimate of a refund liability related to the appeals court decision on MISO return on equity complaints. (See Note 6. Equity Investments.)
Other Income increased $3.9 million from 2021 primarily due to lower pension and other postretirement plan non-service credits. (See Note 1. Operations and Significant Accounting Policies.)
ALLETE, Inc. 2022 Form 10-K
39
2022 Compared to 2021 (Continued)
Regulated Operations (Continued)
Income Tax Benefit decreased $6.2 million from 2021 primarily due to higher pre-tax income and lower production tax credits.
ALLETE Clean Energy
| | | | | | | | |
| Year Ended December 31 | 2022 | 2021 |
| Millions | | |
| Operating Revenue | | |
| Contracts with Customers – Non-utility | $110.7 | | $75.5 | |
Other – Non-utility (a) | 7.6 | | 11.4 | |
| Cost of Sales – Non-utility | 56.7 | | 3.0 | |
| Operating and Maintenance | 47.3 | | 41.5 | |
| Depreciation and Amortization | 58.6 | | 49.2 | |
| Taxes Other than Income Taxes | 10.7 | | 7.1 | |
| Operating Loss | (55.0) | | (13.9) | |
| Interest Expense | (2.3) | | (1.5) | |
| Other Income | 10.8 | | 0.3 | |
| Loss Before Income Taxes | (46.5) | | (15.1) | |
| Income Tax Benefit | (15.4) | | (16.6) | |
| Net Income (Loss) | (31.1) | | 1.5 | |
Net Loss Attributable to Non-Controlling Interest (b) | (47.4) | | (24.8) | |
| Net Income Attributable to ALLETE | $16.3 | | $26.3 | |
(a)Represents non-cash amortization of differences between contract prices and estimated market prices on assumed PSAs.
(b)See Note 1. Operations and Significant Accounting Policies.
Operating Revenue increased $31.4 million, or 36 percent, from 2021 primarily due to revenue from the closing of a portion of ALLETE Clean Energy’s Northern Wind project in December 2022. Operating revenue in 2022 was also impacted by lower realized pricing under the Caddo and Diamond Spring wind energy facilities’ power sales agreements resulting from extreme market volatility and transmission congestion in the Southwest Power Pool. Operating revenue in 2021 included the negative impact related to ALLETE Clean Energy’s Diamond Spring wind energy facility resulting from an extreme winter storm event in the southwest United States in February 2021.
| | | | | | | | | | | | | | |
| Year Ended December 31, |
| 2022 | 2021 |
| Production and Operating Revenue | kWh | Revenue | kWh | Revenue |
| Millions | | | | |
| Wind Energy Regions | | | | |
| East | 266.6 | | $24.3 | | 236.6 | | $21.4 | |
Midwest (a) | 775.9 | | 27.0 | | 882.9 | | 32.2 | |
| South | 2,047.1 | | 15.4 | | 1,009.8 | | 11.2 | |
| West | 829.5 | | 18.1 | | 823.2 | | 22.1 | |
| Total Wind Energy Facilities | 3,919.1 | | 84.8 | | 2,952.5 | | 86.9 | |
| Sale of Wind Energy Facility | — | | 33.5 | | — | | — | |
| Total Production and Operating Revenue | 3,919.1 | | $118.3 | 2,952.5 | | $86.9 | |
(a)The Chanarambie and Viking wind energy facilities were decommissioned in the second quarter of 2022 as part of ALLETE Clean Energy’s Northern Wind project.
Cost of Sales - Non-utility increased $53.7 million from 2021 reflecting additional losses in 2022 related to ALLETE Clean Energy’s project to repower and sell its Northern Wind project resulting from inflationary increases and significant cost pressures. In addition, Cost of Sales – Non-utility in 2022 reflected a $10.2 million reserve in the second quarter of 2022 related to the sale of the Northern Wind project, which was fully offset by a gain on removal of the PSA liability for the Northern Wind project upon decommissioning of the wind energy facilities. (See Other Income and Outlook – ALLETE Clean Energy.)
ALLETE, Inc. 2022 Form 10-K
40
2022 Compared to 2021 (Continued)
ALLETE Clean Energy (Continued)
Operating and Maintenance expense increased $5.8 million, or 14 percent, from 2021 primarily due to operating and maintenance expenses related to the Caddo wind energy facility, which commenced operations in December 2021.
Depreciation and Amortization expense increased $9.4 million, or 19 percent, from 2021 primarily due to additional property, plant and equipment in service related to the Caddo wind energy facility, which commenced operations in December 2021.
Taxes Other Than Income Taxes increased $3.6 million from 2021 primarily due to higher property tax expense related to the Caddo wind energy facility, which commenced operations in December 2021.
Other Income increased $10.5 million from 2021 primarily due to a gain on removal of the PSA liability for the Northern Wind project upon decommissioning of the wind energy facilities. (See Cost of Sales – Non-utility and Outlook – ALLETE Clean Energy.)
Net Loss Attributable to Non-Controlling Interest increased $22.6 million from 2021 reflecting net losses attributable to non-controlling interest for the Caddo wind energy facility as well as higher net losses attributable to non-controlling interests for the Glen Ullin and Diamond Spring wind energy facilities resulting from higher wind resources and a higher PTC value in 2022 compared to 2021.
Corporate and Other
Operating Revenue increased $88.7 million, or 85 percent, from 2021 reflecting revenue from New Energy, which was acquired in April 2022, higher revenue at BNI Energy which operates under cost-plus fixed fee contracts, as a result of higher expenses in 2022 compared to 2021 and higher land sales at ALLETE Properties compared to 2021.
Net Income Attributable to ALLETE was $23.1 million in 2022 compared to $13.8 million in 2021. Net income in 2022 reflects net income from New Energy of $7.8 million, which included a $8.3 million after-tax expense as a result of purchase price accounting related to projects under development at the time of acquisition. Net income in 2022 also reflects higher earnings from our investment in Nobles 2 due to higher wind resources in 2022, higher land sales at ALLETE Properties, earnings from Minnesota solar projects placed into service in 2022 and lower income taxes. These increases were partially offset by transaction costs of $2.7 million after-tax related to the acquisition of New Energy, and higher other expenses compared to 2021. Net income in 2021 included South Shore Energy’s sale of a portion of its interest in NTEC to Basin which resulted in the recognition of an approximately $8.5 million after-tax gain related to prior development costs and risks incurred.
Income Taxes – Consolidated
For the year ended December 31, 2022, the effective tax rate was a benefit of 31.2 percent (benefit of 24.3 percent for the year ended December 31, 2021). The effective tax rate for 2022 was a lower benefit primarily due to lower production tax credits, higher pre-tax income and higher net losses attributable to non-controlling interests in subsidiaries. (See Note 11. Income Tax Expense.)
2021 Compared to 2020
The comparison of the results of operations for the years ended December 31, 2021 and 2020 is included in Management's Discussion in the Annual Report on Form 10-K for the year ended December 31, 2021. We have identified an immaterial prior period error with respect to the recognition of a non-cash impairment expense for our Northern Wind operating assets in 2020, and the prior period results have been revised accordingly for comparability. See Note 1. Operations and Significant Accounting Policies for additional information.
ALLETE, Inc. 2022 Form 10-K
41
Critical Accounting Policies
The preparation of financial statements and related disclosures in conformity with GAAP requires management to make various estimates and assumptions that affect amounts reported in the Consolidated Financial Statements. These estimates and assumptions may be revised, which may have a material effect on the Consolidated Financial Statements. Actual results may differ from these estimates and assumptions. These policies are discussed with the Audit Committee of our Board of Directors on a regular basis. We believe the following policies are most critical to our business and the understanding of our results of operations.
Regulatory Accounting. Our regulated utility operations are subject to accounting standards for the effects of certain types of regulation. These standards require us to reflect the effect of regulatory decisions in our financial statements. Regulatory assets represent incurred costs that have been deferred as they are probable for recovery in customer rates. Regulatory liabilities represent obligations to make refunds to customers and amounts collected in rates for which the related costs have not yet been incurred. The Company assesses quarterly whether regulatory assets and liabilities meet the criteria for probability of future recovery or deferral. This assessment considers factors such as, but not limited to, changes in the regulatory environment and recent rate orders to other regulated entities under the same jurisdiction. If future recovery or refund of costs becomes no longer probable, the assets and liabilities would be recognized in current period net income or other comprehensive income. (See Note 4. Regulatory Matters.)
Pension and Postretirement Health and Life Actuarial Assumptions. We account for our pension and other postretirement benefit obligations in accordance with the accounting standards for defined benefit pension and other postretirement plans. These standards require the use of several important assumptions, including the expected long-term rate of return on plan assets, the discount rate and mortality assumptions, among others, in determining our obligations and the annual cost of our pension and other postretirement benefits. In establishing the expected long-term rate of return on plan assets, we determine the long-term historical performance of each asset class and adjust these for current economic conditions while utilizing the target allocation of our plan assets to forecast the expected long-term rate of return. Our pension asset allocation as of December 31, 2022, was approximately 46 percent equity securities, 50 percent fixed income and 4 percent real estate. Our postretirement health and life asset allocation as of December 31, 2022, was approximately 66 percent equity securities, and 34 percent fixed income. Equity securities consist of a mix of market capitalization sizes with domestic and international securities. In 2022, we used weighted average expected long-term rates of return of 6.00 percent in our actuarial determination of our pension expense and 5.41 percent in our actuarial determination of our other postretirement expense. The actuarial determination uses an asset smoothing methodology for actual returns to reduce the volatility of varying investment performance over time. We review our expected long-term rate of return assumption annually and will adjust it to respond to changing market conditions. A one-quarter percent decrease in the expected long-term rate of return would increase the annual expense for pension and other postretirement benefits by approximately $2.2 million, pre-tax.
The discount rate is computed using a bond matching study which utilizes a portfolio of high quality bonds that produce cash flows similar to the projected costs of our pension and other postretirement plans. In 2022, we used weighted average discount rates of 3.28 percent and 3.09 percent in our actuarial determination of our pension and other postretirement expense, respectively. We review our discount rates annually and will adjust them to respond to changing market conditions. A one-quarter percent decrease in the discount rate would increase the annual expense for pension and other postretirement benefits by approximately $1.0 million, pre-tax.
The mortality assumptions used to calculate our pension and other postretirement benefit obligations as of December 31, 2022, considered a modified PRI-2012 mortality table and MP-2021 mortality projection scale. (See Note 12. Pension and Other Postretirement Benefit Plans.)
Valuation of Business Combinations and Resulting Goodwill. When we acquire a business, the assets acquired and liabilities assumed are recorded at their respective fair values as of the acquisition date. Determining the fair value of intangible assets acquired as part of a business combination requires us to make significant estimates. These estimates may include the amount and timing of projected future cash flows, the discount rate used to discount those cash flows to present value, the assessment of the asset’s life cycle, and the consideration of legal, technical, regulatory, economic and competitive risks.
ALLETE, Inc. 2022 Form 10-K
42
Critical Accounting Policies (Continued)
Goodwill. Goodwill is the excess of the purchase price (consideration transferred) over the estimated fair value of the net assets of the acquired businesses. In accordance with GAAP, goodwill is not amortized. The Company assesses whether there has been an impairment of goodwill annually in the fourth quarter and whenever an event occurs or circumstances change that would indicate the carrying amount may be impaired. Impairment testing for goodwill is done at the reporting unit level. An impairment loss is recognized when the carrying amount of the reporting unit’s net assets exceeds the estimated fair value of the reporting unit. The test for impairment requires us to make several estimates about fair value, most of which are based on projected future cash flows. Our estimates associated with the goodwill impairment test are considered critical due to the amount of goodwill recorded on our Consolidated Balance Sheet and the judgment required in determining fair value. The fair value of the New Energy reporting unit was determined using a discounted cash flow model, using significant assumptions which included a discount rate of 14 percent, cash flow forecasts through 2027, industry average gross margins, and a terminal growth rate of 3.5 percent. Any forecast contains a degree of uncertainty, and changes in the forecasted cash flows and other assumptions could significantly increase or decrease the calculated fair value of New Energy. The results of our annual impairment test are discussed in Note 1. Operations and Significant Accounting Policies and Note 7. Fair Value in this Form 10-K. Goodwill was $154.9 million as of December 31, 2022.
Impairment of Long-Lived Assets. We review our long-lived assets for indicators of impairment in accordance with the accounting standards for property, plant and equipment on a quarterly basis.
In accordance with the accounting standards for property, plant and equipment, if indicators of impairment exist, we test our long-lived assets for recoverability by comparing the carrying amount of the asset to the undiscounted future net cash flows expected to be generated by the asset. Cash flows are assessed at the lowest level of identifiable cash flows. The undiscounted future net cash flows are impacted by trends and factors known to us at the time they are calculated and our expectations related to: management’s best estimate of future sales prices; holding period and timing of sales; method of disposition; and future expenditures necessary to maintain the operations.
Taxation. We are required to make judgments regarding the potential tax effects of various financial transactions and our ongoing operations to estimate our obligations to taxing authorities. These tax obligations include income taxes and taxes other than income taxes. Judgments related to income taxes require the recognition in our financial statements of the largest tax benefit of a tax position that is “more-likely-than-not” to be sustained on audit. Tax positions that do not meet the “more-likely-than-not” criteria are reflected as a tax liability in accordance with the accounting standards for uncertainty in income taxes. We record a valuation allowance against our deferred tax assets to the extent it is more-likely-than-not that some portion or all of the deferred tax assets will not be realized.
We are subject to income taxes in various jurisdictions. We make assumptions and judgments each reporting period to estimate our income tax assets, liabilities, benefits and expenses. Judgments and assumptions are supported by historical data and reasonable projections. Our assumptions and judgments include the application of tax statutes and regulations, and projections of future federal taxable income, state taxable income, and state apportionment to determine our ability to utilize NOL and credit carryforwards prior to their expiration. Significant changes in assumptions regarding future federal and state taxable income or a change in tax rates could require new or increased valuation allowances which could result in a material impact on our results of operations.
ALLETE, Inc. 2022 Form 10-K
43
Outlook
ALLETE is an energy company committed to earning a financial return that rewards our shareholders, allows for reinvestment in our businesses, and sustains growth. The Company has a long-term objective of achieving consolidated earnings per share growth within a range of 5 percent to 7 percent.
ALLETE is predominately a regulated utility through Minnesota Power, SWL&P, and an investment in ATC. ALLETE’s strategy is to remain predominately a regulated utility while investing in ALLETE Clean Energy, New Energy and its Corporate and Other businesses to complement its regulated businesses, balance exposure to the utility’s industrial customers, and provide potential long-term earnings growth. ALLETE expects net income from Regulated Operations to be approximately 75 percent of total consolidated net income in 2023. ALLETE expects its businesses to generally provide regulated, contracted or recurring revenues, and to support sustained growth in net income and cash flow.
On August 16, 2022, the Inflation Reduction Act was signed into law. We believe our businesses will benefit from certain provisions of the legislation including from the extension and transferability of production tax credits and investment tax credits, among others. We do not anticipate any impact from the new alternative minimum tax. We will continue to assess the impact of the legislation as additional implementation guidance becomes available.
Minnesota Carbon-Free Legislation. On February 7, 2023, the Minnesota Governor signed into law legislation that updates the state’s renewable energy standard and requires Minnesota electric utilities to source retail sales with 100 percent carbon-free energy by 2040. The law increases the renewable energy standard from 25 percent renewable by 2025 to 55 percent renewable by 2035, and requires investor-owned Minnesota utilities to provide 80 percent carbon-free energy by 2030, 90 percent carbon-free energy by 2035 and 100 percent carbon-free energy by 2040. The law utilizes renewable energy credits as the means to demonstrate compliance with both the carbon-free and renewable standards, includes an off-ramp provision that enables the MPUC to protect reliability and customer costs through modification or delay of either the renewable energy standard, the carbon-free standard, or both, and streamlines development and construction of wind energy projects and transmission in Minnesota. The Company is evaluating the law to identify challenges and opportunities it could present.
Regulated Operations. Minnesota Power’s long-term strategy is to be the leading electric energy provider in northeastern Minnesota by providing safe, reliable and cost-competitive electric energy, while complying with environmental permit conditions and renewable energy requirements. Keeping the cost of energy production competitive enables Minnesota Power to effectively compete in the wholesale power markets and minimizes retail rate increases to help maintain customer viability. As part of maintaining cost competitiveness, Minnesota Power intends to reduce its exposure to possible future carbon and GHG legislation by reshaping its generation portfolio, over time, to reduce its reliance on coal. Minnesota Power has a goal of delivering 100 percent carbon-free energy by 2050. (See EnergyForward.) We will monitor and review proposed environmental regulations and may challenge those that add considerable cost with limited environmental benefit. Minnesota Power will continue to pursue customer growth opportunities and cost recovery rider approvals for transmission, renewable and environmental investments, as well as work with regulators to earn a fair rate of return.
Regulatory Matters. Entities within our Regulated Operations segment are under the jurisdiction of the MPUC, FERC, PSCW and NDPSC. See Note 4. Regulatory Matters for discussion of regulatory matters within these jurisdictions.
2022 Minnesota General Rate Case. On November 1, 2021, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 18 percent for retail customers. The rate filing seeks a return on equity of 10.25 percent and a 53.81 percent equity ratio. On an annualized basis, the requested final rate increase would generate approximately $108 million in additional revenue. In orders dated December 30, 2021, the MPUC accepted the filing as complete and authorized an annual interim rate increase beginning January 1, 2022, with approximately $80 million expected to be collected in cash and approximately $8 million of interim rates for residential customers deferred with a final determination on recovery at the end of the rate case.
ALLETE, Inc. 2022 Form 10-K
44
Outlook (Continued)
Regulatory Matters (Continued)
At a hearing on January 23, 2023, the MPUC made determinations regarding Minnesota Power’s general rate case including allowing a return on common equity of 9.65 percent and a 52.50 percent equity ratio. Upon commencement of final rates, we expect additional revenue from base rates of approximately $60 million and an additional $10 million in revenue recognized under cost recovery riders on an annualized basis, subject to final written order and reconsideration. Final rates are expected to commence in the third quarter of 2023; interim rates will be collected through this period with reserves recorded as necessary. As a result of the MPUC’s determinations made on January 23, 2023, Minnesota Power has recorded a reserve for an interim rate refund of approximately $18 million pre-tax as of December 31, 2022, which is subject to MPUC approval of Minnesota Power’s refund calculation. In addition, Minnesota Power recorded a charge of approximately $8 million pre-tax to write-off the deferred portion of residential customer interim rates. Minnesota Power also recorded additional revenue of approximately $9 million pre-tax for an increase in expected recoveries under its cost recovery riders. Minnesota Power plans to file its next rate case in the fourth quarter of 2023.
Minnesota Power Land Sales. In August 2020, Minnesota Power filed a petition with the MPUC for approval to sell land that surrounds several reservoirs on its hydroelectric system and is no longer required to maintain its operations. The land has an estimated value of approximately $100 million, and Minnesota Power proposed to credit ratepayers the net proceeds from the sales in a future rate case or through its renewable resources rider to mitigate future rate increases. In an order dated November 18, 2021, the MPUC authorized the land sales and directed the net proceeds to be refunded to ratepayers subject to certain conditions and required compliance filings.
2022 Wisconsin General Rate Case. In 2022, SWL&P filed a rate increase request with the PSCW seeking an average increase of 3.6 percent for retail customers. The filing sought an overall return on equity of 10.4 percent and a 55 percent equity ratio. On an annualized basis, the requested final rate increase would have generated an estimated $4.3 million in additional revenue. In an order dated December 20, 2022, the PSCW approved an annual increase of $3.3 million reflecting a return on equity of 10.0 percent and 55 percent equity ratio. Final rates went into effect January 1, 2023.
Industrial Customers and Prospective Additional Load
Industrial Customers. Electric power is one of several key inputs in the taconite mining, paper, pulp and secondary wood products, pipeline and other industries. Approximately 52 percent of our regulated utility kWh sales in 2022 (47 percent in 2021 and 47 percent in 2020) were made to our industrial customers. We expect industrial sales of approximately 6.5 million MWh in 2023 (6.7 million MWh in 2022 and 7.2 million in 2021). (See Item 1. Business – Regulated Operations – Electric Sales / Customers.)
Taconite. Minnesota Power’s taconite customers are capable of producing up to approximately 41 million tons of taconite pellets annually. Taconite pellets produced in Minnesota are primarily shipped to North American steel making facilities that are part of the integrated steel industry, which continue to lead the world in environmental performance among steelmaking countries. According to the U.S. Department of Energy, steel production in the U.S. is the most energy efficient of any major steel producing country. Steel produced from these North American facilities is used primarily in the manufacture of automobiles, appliances, tubular applications for all industries, and in the construction industry. Steel is also a critical component of the clean energy transformation underway today. Meeting the demand for more renewable energy and the need for additional infrastructure to transport green energy from the point of generation to the end user both require steel. Historically, less than 10 percent of Minnesota taconite production has been exported outside of North America.
There has been a general historical correlation between U.S. steel production and Minnesota taconite production. The American Iron and Steel Institute, an association of North American steel producers, reported that U.S. raw steel production operated at approximately 78 percent of capacity in 2022 (82 percent in 2021 and 68 percent in 2020). The World Steel Association, an association of steel producers, national and regional steel industry associations, and steel research institutes representing approximately 85 percent of world steel production, projected U.S. steel consumption in 2023 will increase by approximately 2 percent compared to 2022.
ALLETE, Inc. 2022 Form 10-K
45
Outlook (Continued)
Industrial Customers and Prospective Additional Load (Continued)
Minnesota Power’s taconite customers may experience annual variations in production levels due to such factors as economic conditions, short-term demand changes or maintenance outages. We expect taconite production from our taconite customers of approximately 33 million tons in 2023. We estimate that a one million ton change in Minnesota Power’s taconite customers’ production would impact our annual earnings per share by approximately $0.04, net of expected power marketing sales at current prices. Changes in wholesale electric prices or customer contractual demand nominations could impact this estimate. Minnesota Power proactively sells power in the wholesale power markets that is temporarily not required by industrial customers to optimize the value of its generating facilities. Long-term reductions in taconite production or a permanent shut down of a taconite customer may lead Minnesota Power to file a general rate case to recover lost revenue.
USS Corporation. USS Corporation has announced plans to invest approximately $150 million to construct a system dedicated to producing direct reduced-grade (DR-grade) pellets at its Keetac plant. USS Corporation broke ground on the project in the third quarter of 2022, which is expected to be completed and producing DR-grade pellets in 2024. This will enable the existing pelletizing plant to not only create DR-grade pellets for use as a feedstock for a direct reduced iron (DRI) or hot briquetted iron (HBI) process that ultimately supplies electric arc furnace steelmaking but also maintains the optionality to continue producing blast furnace-grade pellets. USS Corporation’s Minntac and Keetac plants are large power industrial customers of Minnesota Power. USS Corporation has the capability to produce approximately 15 million and 5 million tons annually at its Minntac and Keetac plants, respectively.
Cleveland-Cliffs, Inc. (Cliffs). In 2020, Cliffs announced that it had completed the previously announced acquisition of substantially all of the operations of ArcelorMittal USA LLC and its subsidiaries. Cliffs had stated that upon closure of the acquisition, Cliffs would be the largest flat-rolled steel producer and the largest iron ore pellet producer in North America. The acquisition included ArcelorMittal’s Minorca mine in Virginia, Minnesota, and its ownership share of Hibbing Taconite in Hibbing, Minnesota, which are both large industrial customers of Minnesota Power. Cliffs is Minnesota Power’s largest customer. The acquisition has increased customer concentration risk for the Company and could lead to further capacity consolidation for both steel blast furnaces and related Minnesota iron ore production.
Cliffs completed construction of a hot briquetted iron production plant in Toledo, Ohio, in 2020, which has utilized direct reduced-grade pellets from Northshore Mining. In October 2021, Cliffs indicated it plans to move direct reduced-grade pellet production to its Minorca mine and that Northshore Mining would become a “swing facility” due to the higher royalty rates at that mine. (See Northshore Mining.).
Northshore Mining. On February 11, 2022, Cliffs announced that with the use of additional scrap in its basic oxygen furnaces, its iron ore needs are not as high as before. In determining where to adjust production, Cliffs decided to idle all production at its Northshore mine until at least April 2023. Cliffs has also indicated that going forward it will be limiting the tonnage of iron ore pellets sold to third parties. Northshore Mining has the capability to produce approximately 6 million tons annually. Minnesota Power has a PSA through 2031 with Silver Bay Power, which provides the majority of the electric service requirements for Northshore Mining. (See Cliffs.)
Silver Bay Power. In 2016, Minnesota Power and Silver Bay Power entered into a PSA through 2031. Silver Bay Power supplies approximately 90 MW of load to Northshore Mining, an affiliate of Silver Bay Power, which had previously been served predominately through self-generation by Silver Bay Power. Starting in 2016, Minnesota Power supplied Silver Bay Power with at least 50 MW of energy and Silver Bay Power had the option to purchase additional energy from Minnesota Power as it transitioned away from self-generation. In 2019, Silver Bay Power ceased self-generation and Minnesota Power began supplying the full energy requirements for Silver Bay Power.
Hibbing Taconite. Hibbing Taconite is a joint venture between subsidiaries of Cliffs (85.3 percent ownership) and USS Corporation (14.7 percent ownership). The joint venture is managed by Cliffs and is also a Large Power Customer of Minnesota Power. Hibbing Taconite has the capability of producing 8 million tons of taconite annually. Hibbing Taconite has proven mineral reserves to support its operations through 2026; and is actively seeking additional mineral reserves to operate beyond its currently stated mine life.
ALLETE, Inc. 2022 Form 10-K
46
Outlook (Continued)
Industrial Customers and Prospective Additional Load (Continued)
Minnesota Sulfate Wild Rice Water Quality Standard. On April 29, 2021, the EPA identified rivers and lakes in Minnesota in which wild rice grows that have sulfate levels that exceed Minnesota’s sulfate limit for wild rice waters. On September 1, 2021, three additional wild rice waters with sulfate levels that exceed Minnesota’s sulfate limit were identified. The EPA directed the MPCA to add these rivers and lakes to its list of impaired waters which can be used to set limits in discharge permits for industrial activities such as mining. Minnesota Power’s taconite customers could be adversely impacted if they are required to significantly reduce sulfate discharges.
Paper, Pulp and Secondary Wood Products. The North American paper and pulp industry continues to face declining demand due to the impact of electronic substitution for print and changing customer needs. As a result, certain paper and pulp customers have reduced their existing operations in recent years and have pursued or are pursuing product changes in response to the declining demand. The resulting reduction in production capacity outside of Minnesota for certain paper grades has solidified our paper customers’ operations, at least for the near term, and as such we expect operating levels in 2023 at the major paper and pulp mills we serve to be at similar levels as in 2022.
ST Paper. In May 2021, ST Paper announced it had completed the purchase of the Duluth Mill from Verso Corporation. ST Paper is completing a project at the Duluth Mill to produce tissue. In January 2022, Minnesota Power entered into an electric service agreement with ST Paper that would begin Large Power Customer service with a minimum term of six years upon start-up of operations, which is anticipated in 2023. A petition for approval of the electric service agreement was approved by the MPUC in May 2022. Upon start-up of operations, ST Paper will become a Large Power Customer as we expect to serve requirements of at least 10 MW of customer load.
Pipeline and Other Industries.
Cenovus Energy. In 2018, a fire at Cenovus Energy’s refinery in Superior, Wisconsin, which was owned by Husky Energy at that time, disrupted operations at the facility. Under normal operating conditions, SWL&P provides approximately 14 MW of average monthly demand to the refinery in addition to water service. The facility remains at minimal operations, and the refinery is expected to resume normal operations in 2023.
Prospective Additional Load. Minnesota Power is pursuing new wholesale and retail loads in and around its service territory. Currently, several companies in northeastern Minnesota continue to progress in the development of natural resource-based projects that represent long-term growth potential and load diversity for Minnesota Power. We cannot predict the outcome of these projects.
EnergyForward. Minnesota Power is executing EnergyForward, its strategy assuring reliability, protecting affordability and further improving environmental performance. The plan includes completed and planned investments in wind, solar, natural gas and hydroelectric power, construction of additional transmission capacity, the installation of emissions control technology and the idling and retirement of certain coal-fired generating facilities. Minnesota Power has a vision to deliver 100 percent carbon-free energy to customers by 2050, continuing its commitment to climate, customers and communities through its EnergyForward strategy. This vision builds on Minnesota Power’s recent achievement of now providing 50 percent renewable energy to its customers.
2021 Integrated Resource Plan (IRP). On February 1, 2021, Minnesota Power filed its latest IRP, which was approved by the MPUC in an order dated January 9, 2023. The approved IRP, which reflects a joint agreement reached with various stakeholders, outlines Minnesota Power’s clean-energy transition plans through 2035. These plans include expanding its renewable energy supply, achieving coal-free operations at its facilities by 2035, and investing in a resilient and flexible transmission and distribution grid. As part of these plans, Minnesota Power anticipates adding up to 700 MW of new wind and solar energy resources, and ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. Minnesota Power’s plans recognize that advances in technology will play a significant role in completing its transition to carbon-free energy supply, reliably and affordably. Minnesota Power is expected to file its next IRP by March 1, 2025.
In recent years, Minnesota Power has transformed its energy supply from more than a 95 percent reliance on coal to become a leader in the nation’s clean-energy transformation. Since 2013, the company has closed or converted seven of its nine coal-fired units and added nearly 900 megawatts of renewable energy sources. Additionally, Minnesota Power has been a leader in energy conservation, surpassing the state’s conservation goals each year for the past decade.
ALLETE, Inc. 2022 Form 10-K
47
Outlook (Continued)
EnergyForward (Continued)
Nemadji Trail Energy Center (NTEC). In 2017, Minnesota Power submitted a resource package to the MPUC which included requesting approval of a natural gas capacity dedication and other affiliated-interest agreements for NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting in 2025 pursuant to the capacity dedication agreement.
Renewable Energy. Minnesota Power continues to execute its renewable energy strategy and recently reached its goal of supplying 50 percent of its energy by renewable energy sources. Minnesota Power also has a goal of delivering 100 percent carbon-free energy by 2050. (See EnergyForward.)
Minnesota Power has approved cost recovery riders for certain renewable investments and expenditures as well as investments and expenditures related to compliance with the Minnesota Solar Energy Standard. The cost recovery riders allow Minnesota Power to charge retail customers on a current basis for the costs of certain renewable and solar investments and expenditures plus a return on the capital invested. (See Note 4. Regulatory Matters.)
Wind Energy. Minnesota Power’s wind energy facilities consist of Bison (497 MW) located in North Dakota, and Taconite Ridge (25 MW) located in northeastern Minnesota. Minnesota Power also has two long-term wind energy PPAs with an affiliate of NextEra Energy, Inc. to purchase the output from Oliver Wind I (50 MW) and Oliver Wind II (48 MW) located in North Dakota.
Minnesota Power uses the 465-mile, 250-kV DC transmission line that runs from Center, North Dakota, to Duluth, Minnesota, to transport wind energy from North Dakota while gradually phasing out coal-based electricity delivered to its system over this transmission line from Square Butte’s lignite coal-fired generating unit. Minnesota Power is currently pursuing a modernization and capacity upgrade of its DC transmission system to continue providing reliable operations and additional system capabilities.
Nobles 2 PPA. Minnesota Power has a long-term PPA with Nobles 2 that provides for Minnesota Power to purchase the energy and associated capacity from a 250 MW wind energy facility in southwestern Minnesota through 2040. The agreement provides for the purchase of output from the facility at fixed energy prices. There are no fixed capacity charges, and Minnesota Power will only pay for energy as it is delivered. (See Corporate and Other – Investment in Nobles 2.)
Manitoba Hydro. Minnesota Power has two long-term PPAs with Manitoba Hydro. The first PPA provides for Minnesota Power to purchase 250 MW of capacity and energy from Manitoba Hydro through May 2035. The second PPA provides for Minnesota Power to purchase up to 133 MW of energy from Manitoba Hydro through June 2040. (See Note 9. Commitments, Guarantees and Contingencies.)
Solar Energy. Minnesota Power’s solar energy supply consists of Camp Ripley, a 10 MW solar energy facility at the Camp Ripley Minnesota Army National Guard base and training facility near Little Falls, Minnesota, and a community solar garden in northeastern Minnesota, which is comprised of a 1 MW solar array owned and operated by a third party with the output purchased by Minnesota Power and a 40 kW solar array that is owned and operated by Minnesota Power. SWL&P also plans to construct a 470 kW solar array in 2023 as part of a community solar garden in Superior, Wisconsin, which was approved by the PSCW in October 2020.
In June 2020, Minnesota Power filed a proposal with the MPUC to accelerate its plans for purchasing solar energy from approximately 20 MW of solar energy projects in Minnesota which was approved in a June 2021 order. These solar energy projects will be constructed and owned through an ALLETE subsidiary with an estimated investment of $40 million. Construction of these solar energy projects commenced in 2022 and will be operational in 2023.
Transmission. We continue to make investments in transmission opportunities that strengthen or enhance the transmission grid or take advantage of our geographical location between sources of renewable energy and end users. These include the GNTL, investments to enhance our own transmission facilities, investments in other transmission assets (individually or in combination with others) and our investment in ATC. See Item 1. Business – Regulated Operations and Note 9. Commitments, Guarantees and Contingencies.
ALLETE, Inc. 2022 Form 10-K
48
Outlook (Continued)
Transmission (Continued)
North Plains Connector Development Agreement. ALLETE and Grid United LLC, an independent transmission company, have signed a memorandum of understanding to explore transmission opportunities, with plans to execute a North Plains Connector development agreement in the first half of 2023. The project is a new, approximately 385-mile high-voltage direct-current (HVDC) transmission line from central North Dakota, to Colstrip, Montana that will be the first transmission connection between three regional U.S. electric energy markets— MISO, the Western Interconnection and the Southwest Power Pool. This new link, open to all sources of electric generation, would create 3,000 MW of transfer capacity between the middle of the country and the West Coast, easing congestion on the transmission system, increasing resiliency and reliability in all three energy markets, and enabling fast sharing of renewable energy across a vast area with diverse weather patterns. The project is expected to cost approximately $2.5 billion. ALLETE expects to pursue at least 35 percent ownership and would oversee the line’s operation. The companies expect project permitting to start in 2023 as they work toward an in-service date of 2029, pending regulatory approvals.
Duluth Loop Reliability Project. On October 21, 2021, Minnesota Power submitted an application for a certificate of need for the Duluth Loop Reliability Project. This transmission project was proposed to enhance reliability in and around Duluth, Minnesota. The project includes the construction of a new 115-kV transmission line; construction of an approximately one-mile extension of an existing 230-kV transmission line; and upgrades to several substations. A certificate of need and route permit are expected in first quarter of 2023. The Duluth Loop Reliability Project is expected to be completed and in service by 2025, subject to MPUC approval, with an estimated cost of $50 million to $70 million.
MISO Long Range Transmission Plan. Minnesota Power and Great River Energy announced on July 25, 2022, their intent to build a 150-mile, 345-kV transmission line, connecting northern Minnesota to central Minnesota to support continued reliability in the Upper Midwest. Great River Energy, a wholesale electric power cooperative, and Minnesota Power filed a Notice of Intent to Construct, Own and Maintain the transmission line with the MPUC on August 1, 2022. This joint project is part of a portfolio of transmission projects approved on July 25, 2022, by MISO, as part of the first phase of its Long Range Transmission Plan. Planning for the $970 million transmission line is in its early stages with the route anticipated to generally follow existing rights of way in an established power line corridor. The two utilities expect to seek a combined Certificate of Need and Route Permit from the MPUC. The MPUC will determine the final route as well as cost recovery for Minnesota Power’s approximately 50 percent estimated share of the project. Subject to regulatory approvals, the transmission line is expected to be in service in 2030.
Investment in ATC. ATC’s most recent 10-year transmission assessment, which covers the years 2022 through 2031, identifies a need for between $5.1 billion and $6.2 billion in transmission system investments. These investments by ATC, if undertaken, are expected to be funded through a combination of internally generated cash, debt and investor contributions. As opportunities arise, we plan to make additional investments in ATC through general capital calls based upon our pro rata ownership interest in ATC.
ALLETE Clean Energy.
ALLETE Clean Energy will pursue growth through acquisitions or project development. ALLETE Clean Energy is targeting acquisitions of existing operating portfolios which have a mix of long-term PSAs in place and/or available for repowering and recontracting. Further, ALLETE Clean Energy will evaluate actions that will lead to the addition of complimentary clean energy products and services. At this time, ALLETE Clean Energy is focused on actions that will optimize its clean energy project portfolio of operating and development projects, which may include recontracting, repowering, entering into partnerships and divestitures along with continued acquisitions or development of new projects including wind, solar, energy storage or storage ready facilities across North America.
Portions of our ALLETE Clean Energy business are experiencing return pressures that are impacting our earnings per share growth from increased competition, and lower forward price curves, as a growing amount of investment capital is being directed into wind generation opportunities. In addition, current and potential new project developments can be negatively affected by a lower ALLETE stock price, which may result in such projects not being accretive, or otherwise unable to satisfy our financial objectives criteria to proceed. In response to these market pressures, we are actively evaluating additional growth opportunities to deliver more comprehensive clean energy solutions for customers at ALLETE Clean Energy, which may include wind, solar, storage solutions, and related energy infrastructure investments and services. We believe that the renewable energy industry is entering a new phase of growth and that we are well-positioned to serve customers and drive future growth at ALLETE. ALLETE Clean Energy will continue to optimize its existing wind energy facility portfolio, seek development of its remaining safe harbor inventory of tax credit qualified turbines, and explore other renewable energy opportunities to expand its service offerings to further enhance its growth and profitability.
ALLETE, Inc. 2022 Form 10-K
49
Outlook (Continued)
ALLETE Clean Energy (Continued)
In May 2021, ALLETE Clean Energy announced that it acquired the rights to the approximately 92 MW Red Barn wind development project and the approximately 68 MW Whitetail renewable development project in southwestern Wisconsin. ALLETE Clean Energy also signed an asset sale agreement for the completed Red Barn wind project with Wisconsin Public Service Corporation and Madison Gas and Electric Company. At a hearing in January 2022, the PSCW approved the sale of the Red Barn wind project, which is expected to close in 2023, subject to completion of construction and receipt of permits.
ALLETE Clean Energy manages risk by having a diverse portfolio of assets, which includes PSA expiration, technology and geographic diversity. The current operating portfolio is subject to typical variations in seasonal wind with higher wind resources typically available in the winter months. The majority of its planned maintenance leverages this seasonality and is performed during lower wind periods. ALLETE Clean Energy’s current operating portfolio is as follows:
| | | | | | | | | | | | | | |
| Region | Wind Energy Facility | Capacity MW | PSA MW | PSA Expiration |
| East | Armenia Mountain | 101 | 100% | 2024 |
| Midwest | Lake Benton | 104 | 100% | 2028 |
| Storm Lake I | 108 | 100% | 2027 |
| Storm Lake II | 77 | | |
| Merchant | | 90% | n/a |
| PSA 1 | | 10% | 2032 |
| Other | 17 | 100% | 2028 |
| South | Caddo | 303 | | |
| Merchant | | 27% | n/a |
| PSA 1 | | 66% | 2034 |
| PSA 2 | | 7% | 2034 |
| Diamond Spring | 303 | | |
| PSA 1 | | 58% | 2035 |
| PSA 2 | | 25% | 2032 |
| PSA 3 | | 16% | 2035 |
| West | Condon | 50 | 100% | (a) |
| Glen Ullin | 106 | 100% | 2039 |
| South Peak | 80 | 100% | 2035 |
(a)The PSA for Condon expired in 2022, and Condon is currently selling energy pursuant to a month-to-month agreement while the parties negotiate an agreement on a new PSA.
Non-cash amortization to revenue recognized by ALLETE Clean Energy relates to the amortization of differences between contract prices and estimated market prices on assumed PSAs. As part of wind energy facility acquisitions, ALLETE Clean Energy assumed various PSAs that were above or below estimated market prices at the time of acquisition; the resulting differences between contract prices and estimated market prices are amortized to revenue over the remaining PSA term. Non-cash amortization is expected to be approximately $5 million in 2023, $6 million annually in 2024 through 2027, and decreasing thereafter through 2032.
Corporate and Other.
New Energy. New Energy is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. New Energy is a leading developer of community, commercial and industrial, and small utility-scale renewable energy projects that has completed more than 400 MW in its history, totaling more than $1 billion of capital deployed. New Energy currently has a robust project pipeline with greater than 2,000 MW of renewable projects in development across 26 different states. New Energy adds value through cost effective development and economies of scale on project implementation, bringing national capabilities to regional co-development partners. New Energy is involved in greenfield development as well as acquiring and completing mid-stage and late-stage renewable energy projects.
Investment in Nobles 2. Our subsidiary, ALLETE South Wind, owns a 49 percent equity interest in Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20-year PPA with Minnesota Power. We account for our investment in Nobles 2 under the equity method of accounting. (See Note 6. Equity Investments.)
ALLETE, Inc. 2022 Form 10-K
50
Outlook (Continued)
Corporate and Other (Continued)
South Shore Energy. South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary, is developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting in 2027 pursuant to a capacity dedication agreement. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $700 million, of which South Shore Energy’s portion is expected to be approximately $150 million. South Shore Energy’s portion of NTEC project costs incurred through December 31, 2022, is approximately $7 million.
BNI Energy. In 2022, BNI Energy sold 3.7 million tons of coal (3.9 million tons in 2021) and anticipates 2023 sales will be higher than 2022. BNI Energy operates under cost-plus fixed fee agreements extending through December 31, 2037.
ALLETE Properties. Our strategy incorporates the possibility of a bulk sale of the entire ALLETE Properties portfolio. Proceeds from a bulk sale would be strategically deployed to support growth initiatives at our Regulated Operations and ALLETE Clean Energy. ALLETE Properties also continues to pursue sales of individual parcels over time and will continue to maintain key entitlements and infrastructure.
Income Taxes
ALLETE’s aggregate federal and multi-state statutory tax rate is approximately 28 percent for 2022. ALLETE also has tax credits and other tax adjustments that reduce the combined statutory rate to the effective tax rate. These tax credits and adjustments historically have included items such as production tax credits, excess deferred taxes, non-controlling interests in subsidiaries, as well as other items. The annual effective rate can also be impacted by such items as changes in income before income taxes, state and federal tax law changes that become effective during the year, business combinations, tax planning initiatives and resolution of prior years’ tax matters. We expect our effective tax rate to be a benefit of approximately 5 percent for 2023 primarily due to federal production tax credits as a result of wind energy generation and non-controlling interests in subsidiaries. We also expect that our effective tax rate will be lower than the combined statutory rate over the next 10 years due to production tax credits attributable to our wind energy generation.
ALLETE, Inc. 2022 Form 10-K
51
Liquidity and Capital Resources
Liquidity Position. ALLETE is well-positioned to meet its liquidity needs. As of December 31, 2022, we had cash and cash equivalents of $36.4 million, $411.6 million in available consolidated lines of credit, 2.1 million original issue shares of common stock available for issuance through a distribution agreement with Lampert Capital Markets and a debt-to-capital ratio of 37 percent.
Capital Structure. ALLETE’s capital structure for each of the last three years is as follows:
| | | | | | | | | | | | | | | | | | | | |
| As of December 31 | 2022 | % | 2021 | % | 2020 | % |
| Millions | | | | | | |
ALLETE Equity (a) | $2,691.9 | | 51 | | $2,404.3 | | 49 | | $2,285.8 | | 50 | |
| Non-Controlling Interest in Subsidiaries | 656.4 | | 12 | | 533.2 | | 11 | | 505.6 | | 11 | |
Short-Term and Long-Term Debt (b) | 1,929.1 | | 37 | | 1,986.4 | | 40 | | 1,806.4 | | 39 | |
| | | | | | |
| $5,277.4 | | 100 | | $4,923.9 | | 100 | | $4,597.8 | | 100 | |
(a) See Immaterial Revision to Prior Period in Note 1. Operations and Significant Accounting Policies.
(b) Excludes unamortized debt issuance costs.
Cash Flows. Selected information from ALLETE’s Consolidated Statement of Cash Flows is as follows:
| | | | | | | | | | | |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Millions | | | |
| Cash, Cash Equivalents and Restricted Cash at Beginning of Period | $47.7 | | $65.2 | | $92.5 | |
| Cash Flows from (used in) | | | |
| Operating Activities | 221.3 | | 263.5 | | 299.8 | |
| Investing Activities | (384.0) | | (485.2) | | (812.8) | |
| Financing Activities | 155.2 | | 204.2 | | 485.7 | |
| Change in Cash, Cash Equivalents and Restricted Cash | (7.5) | | (17.5) | | (27.3) | |
| Cash, Cash Equivalents and Restricted Cash at End of Period | $40.2 | | $47.7 | | $65.2 | |
Operating Activities. Cash provided by operating activities was lower in 2022 compared to 2021. Cash provided by operating activities in 2022 reflected higher payments for inventories, net of customer deposits received, compared to 2021 primarily related to ALLETE Clean Energy’s Northern Wind and Red Barn projects. This decrease was partially offset by the timing of recovery under the fuel adjustment clause.
Cash provided by operating activities was lower in 2021 compared to 2020. Cash from operating activities in 2021 included lower net income and higher payments for inventories compared to 2020, and was negatively impacted by the timing of recovery under the fuel adjustment clause.
Investing Activities. Cash used in investing activities was lower in 2022 compared to 2021. Cash used for investing activities in 2022 reflected lower additions to property, plant and equipment and lower payments for equity method investments compared to 2021. These decreases were partially offset by cash payments for the acquisition of New Energy.
Cash used in investing activities was lower in 2021 compared to 2020. Cash used for investing activities in 2021 reflected lower additions to property, plant and equipment and lower payments for equity method investments compared to 2020.
Financing Activities. Cash provided by financing activities was lower in 2022 compared to 2021 primarily due to higher repayments of short-term and long-term debt and higher dividends on common stock in 2022. These decreases were partially offset by higher proceeds from the issuance of common stock, higher proceeds from issuance of short-term and long-term debt, and higher proceeds from non-controlling interest in 2022.
Cash provided by financing activities was lower in 2021 compared to 2020 primarily due to lower proceeds from non-controlling interest in subsidiaries and higher repayments of short-term and long-term debt in 2021. These decreases were partially offset by higher proceeds from the issuance of common stock and higher proceeds from the issuance of short-term and long-term debt in 2021.
ALLETE, Inc. 2022 Form 10-K
52
Liquidity and Capital Resources (Continued)
Working Capital. Additional working capital, if and when needed, generally is provided by consolidated bank lines of credit and the issuance of securities, including long-term debt, common stock and commercial paper. As of December 31, 2022, we had consolidated bank lines of credit aggregating $475.7 million ($432.0 million as of December 31, 2021), most of which expire in January 2026. We had $32.8 million outstanding in standby letters of credit and $31.3 million outstanding draws under our lines of credit as of December 31, 2022 ($31.5 million in standby letters of credit and $159.7 million outstanding draws as of December 31, 2021). We also have other credit facility agreements in place that provide the ability to issue up to $252.0 million in standby letters of credit. As of December 31, 2022, we had $245.4 million outstanding in standby letters of credit under these agreements.
In addition, as of December 31, 2022, we had 2.9 million original issue shares of our common stock available for issuance through Invest Direct and 2.1 million original issue shares of common stock available for issuance through a distribution agreement with Lampert Capital Markets. (See Securities.) The amount and timing of future sales of our securities will depend upon market conditions and our specific needs.
Securities. We entered into a distribution agreement with Lampert Capital Markets, in 2008, as amended most recently in 2020, with respect to the issuance and sale of up to an aggregate of 13.6 million shares of our common stock, without par value, of which 2.1 million shares remain available for issuance as of December 31, 2022. For the year ended December 31, 2022, no shares of common stock were issued under this agreement (0.8 million shares for net proceeds of $51.0 million in 2021; none in 2020).
During the year ended December 31, 2022, we issued 0.3 million shares of common stock through Invest Direct, the Employee Stock Purchase Plan and the Retirement Savings and Stock Ownership Plan, resulting in net proceeds of $16.2 million (0.3 million shares for net proceeds of $18.9 million in 2021; 0.4 million shares for net proceeds of $18.1 million in 2020). See Note 10. Common Stock and Earnings Per Share for additional detail regarding ALLETE’s equity securities.
On April 5, 2022, ALLETE issued and sold approximately 3.7 million shares of ALLETE common stock. Net proceeds of approximately $224 million were received from the sale of shares. Proceeds were used primarily to fund the acquisition of New Energy and capital investments at ALLETE Clean Energy.
Financial Covenants. See Note 8. Short-Term and Long-Term Debt for information regarding our financial covenants.
Pension and Other Postretirement Benefit Plans. Management considers various factors when making funding decisions, such as regulatory requirements, actuarially determined minimum contribution requirements and contributions required to avoid benefit restrictions for the defined benefit pension plans. For the year ended December 31, 2022, we made no contributions to the defined benefit pension plans. On January 17, 2023, we contributed $6.5 million in cash to the defined benefit pension plans. We do not expect to make any further contributions to our defined benefit pension plans in 2023, and we do not expect to make any contributions to our other postretirement benefit plans in 2023. (See Note 10. Common Stock and Earnings Per Share and Note 12. Pension and Other Postretirement Benefit Plans.)
Off-Balance Sheet Arrangements. Off-balance sheet arrangements are discussed in Note 9. Commitments, Guarantees and Contingencies.
Contractual Obligations and Commercial Commitments. ALLETE has contractual obligations and other commitments that will need to be funded in the future, in addition to its capital expenditure programs. Material contractual obligations and other commitments are as follows:
Long-Term Debt. ALLETE has material long-term debt obligations, including long-term debt due within one year. These obligations include the principal amount of bonds, notes and loans which are recorded on the Consolidated Balance Sheet, plus interest. (See Note 8. Short-Term and Long‑Term Debt.)
Pension and Other Postretirement Benefit Plans. Pension and other postretirement benefit plan obligations include the current estimate of future benefit payments. Pension contributions are dependent on several factors including realized asset performance, future discount rate and other actuarial assumptions, Internal Revenue Service and other regulatory requirements, and contributions required to avoid benefit restrictions for the pension plans. Funding for the other postretirement benefit plans is impacted by realized asset performance, future discount rate and other actuarial assumptions, and utility regulatory requirements. Our obligations are estimates and will change based on actual market performance, changes in interest rates and any changes in governmental regulations. (See Note 12. Pension and Other Postretirement Benefit Plans.)
ALLETE, Inc. 2022 Form 10-K
53
Liquidity and Capital Resources (Continued)
Operating Lease Obligations. ALLETE has certain operating lease obligations for the minimum payments required under various lease agreements which are recorded on the Consolidated Balance Sheet. (See Note 1. Operations and Significant Accounting Policies.)
Easement Obligations. ALLETE has easement obligations for the minimum payments required under our land easement agreements at our wind energy facilities. (See Note 9. Commitments, Guarantees and Contingencies.)
PPA Obligations. PPA obligations represent our Square Butte, Manitoba Hydro and other PPAs. (See Note 9. Commitments, Guarantees and Contingencies.)
Other Purchase Obligations. ALLETE has other purchase obligations covering our minimum purchase commitments under coal supply and rail contracts, and long-term service agreements for wind energy facilities. (See Note 9. Commitments, Guarantees and Contingencies.)
Credit Ratings. Access to reasonably priced capital markets is dependent in part on credit and ratings. Our securities have been rated by S&P and by Moody’s. Rating agencies use both quantitative and qualitative measures in determining a company’s credit rating. These measures include business risk, liquidity risk, competitive position, capital mix, financial condition, predictability of cash flows, management strength and future direction. Some of the quantitative measures can be analyzed through a few key financial ratios, while the qualitative ones are more subjective. Our current credit ratings are listed in the following table:
| | | | | | | | |
| Credit Ratings | S&P | Moody’s |
| Issuer Credit Rating | BBB | Baa1 |
| Commercial Paper | A-2 | P-2 |
| First Mortgage Bonds | (a) | A2 |
(a) Not rated by S&P.
The disclosure of these credit ratings is not a recommendation to buy, sell or hold our securities. Ratings are subject to revision or withdrawal at any time by the assigning rating organization. Each rating should be evaluated independently of any other rating.
Common Stock Dividends. ALLETE is committed to providing a competitive dividend to its shareholders while at the same time funding its growth. ALLETE’s long-term objective is to maintain a dividend payout ratio similar to our peers and provide for future dividend increases. Our targeted payout range is between 60 percent and 70 percent. In 2022, we paid out 77 percent (78 percent in 2021; 78 percent in 2020) of our per share earnings in dividends. On February 3, 2023, our Board of Directors declared a dividend of $0.6775 per share, which is payable on March 1, 2023, to shareholders of record at the close of business on February 15, 2023.
ALLETE, Inc. 2022 Form 10-K
54
Capital Requirements
ALLETE’s projected capital expenditures for the years 2023 through 2027 are presented in the following table. Actual capital expenditures may vary from the projections due to changes in forecasted plant maintenance, regulatory decisions or approvals, future environmental requirements, base load growth, capital market conditions or executions of new business strategies. Projected capital expenditures exclude amounts for projects that will be sold to third parties upon completion.
| | | | | | | | | | | | | | | | | | | | | | | |
| Capital Expenditures | 2023 | 2024 | 2025 | 2026 | 2027 | Total |
| Millions | | | | | | |
| Regulated Operations | | | | | | |
| | High kV Transmission Expansion | $40 | | $55 | | $135 | | $190 | | $270 | | $690 | |
| Solar 300 MW (a) | — | | 150 | | 200 | | 175 | | 100 | | 625 | |
| Wind 150 MW (a) | — | | — | | 105 | | 175 | | — | | 280 | |
| | Storage (a) | — | | 10 | | 20 | | — | | 100 | | 130 | |
| Base & Other | 190 | | 265 | | 250 | | 235 | | 190 | | 1,130 | |
| Regulated Operations | $230 | | $480 | | $710 | | $775 | | $660 | | $2,855 | |
ALLETE Clean Energy (b) | 10 | | 5 | | 5 | | 5 | | 5 | | 30 | |
| | | | | | |
| Corporate and Other | | | | | | |
| | | | | | | |
| South Shore Energy (c) | 40 | | 55 | | 35 | | 5 | | — | | 135 | |
| Other | 20 | | 10 | | 15 | | 15 | | 20 | | 80 | |
Total Capital Expenditures (d) | $300 | | $550 | | $765 | | $800 | | $685 | | $3,100 | |
(a)These capital expenditures are part of Minnesota Power’s clean-energy transition plans, which include its vision to deliver 100 percent carbon-free energy to customers by 2050, as detailed in Minnesota Power’s latest IRP, which was approved by the MPUC in January 2023. These capital expenditures are dependent on successful requests for proposal by Minnesota Power. (See Outlook – EnergyForward.)
(b)Capital expenditures in 2023 do not include costs related to ALLETE Clean Energy’s project to develop and sell the 92 MW Red Barn project as these projects will be sold upon completion. (See Outlook – ALLETE Clean Energy.)
(c)Our portion of estimated capital expenditures for construction of NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy.
(d)These amounts do not include any capital expenditures related to the North Plains Connector Development Agreement. (See Outlook – Transmission.)
We are well positioned to meet our financing needs due to adequate operating cash flows, available additional working capital and access to capital markets. We will finance capital expenditures from a combination of internally generated funds, debt and equity issuance proceeds. We intend to maintain a capital structure with capital ratios near current levels. (See Capital Structure.)
Environmental and Other Matters
Our businesses are subject to regulation of environmental matters by various federal, state and local authorities. A number of regulatory changes to the Clean Air Act, the Clean Water Act and various waste management requirements have been promulgated by both the EPA and state authorities over the past several years. Minnesota Power’s facilities are subject to additional requirements under many of these regulations. Minnesota Power is reshaping its generation portfolio, over time, to reduce its reliance on coal, has installed cost-effective emission control technology, and advocates for sound science and policy during rulemaking implementation. (See Note 9. Commitments, Guarantees and Contingencies.)
Market Risk
Securities Investments.
Available-for-Sale Securities. As of December 31, 2022, our available-for-sale securities portfolio consisted primarily of securities held in other postretirement plans to fund employee benefits.
ALLETE, Inc. 2022 Form 10-K
55
Market Risk (Continued)
INTEREST RATE RISK
We are exposed to risks resulting from changes in interest rates as a result of our issuance of variable rate debt. We manage our interest rate risk by varying the issuance and maturity dates of our fixed rate debt, limiting the amount of variable rate debt, and continually monitoring the effects of market changes in interest rates. We may also enter into derivative financial instruments, such as interest rate swaps, to mitigate interest rate exposure. The following table presents the long-term debt obligations and the corresponding weighted average interest rate as of December 31, 2022:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Expected Maturity Date |
Interest Rate Sensitive
Financial Instruments | 2023 | 2024 | 2025 | 2026 | 2027 | Thereafter | Total | Fair Value |
| Long-Term Debt | | | | | | | | |
| Fixed Rate – Millions | $91.9 | | $87.3 | | $216.1 | | $79.4 | | $81.7 | | $1,154.4 | | $1,710.8 | | $1,564.4 | |
| Average Interest Rate – % | 5.9 | | 4.4 | | 3.4 | | 3.4 | | 5.7 | | 4.0 | | 4.1 | | |
| | | | | | | | |
| Variable Rate – Millions | — | | $7.5 | | $170.0 | | — | | $40.8 | | — | | $218.3 | | $218.3 | |
| Average Interest Rate – % | — | | 7.8 | | 4.8 | | — | | 4.2 | | — | | 4.8 | | |
Interest rates on variable rate long-term debt are reset on a periodic basis reflecting prevailing market conditions. Based on the variable rate debt outstanding as of December 31, 2022, an increase of 100 basis points in interest rates would impact the amount of pre-tax interest expense by $2.2 million. This amount was determined by considering the impact of a hypothetical 100 basis point increase to the average variable interest rate on the variable rate debt outstanding as of December 31, 2022.
COMMODITY PRICE RISK
Our regulated utility operations incur costs for power and fuel (primarily coal and related transportation) in Minnesota, and power and natural gas purchased for resale in our regulated service territory in Wisconsin. Minnesota Power’s exposure to price risk for these commodities is significantly mitigated by the current ratemaking process and regulatory framework, which allows recovery of fuel costs in excess of those included in base rates or distribution of savings in fuel costs to ratepayers. SWL&P’s exposure to price risk for natural gas is significantly mitigated by the current ratemaking process and regulatory framework, which allows the commodity cost to be passed through to customers. We seek to prudently manage our customers’ exposure to price risk by entering into contracts of various durations and terms for the purchase of power and coal and related transportation costs (Minnesota Power) and natural gas (SWL&P).
POWER MARKETING
Minnesota Power’s power marketing activities consist of: (1) purchasing energy in the wholesale market to serve its regulated service territory when energy requirements exceed generation output; and (2) selling excess available energy and purchased power. From time to time, Minnesota Power may have excess energy that is temporarily not required by retail and municipal customers in our regulated service territory. Minnesota Power actively sells any excess energy to the wholesale market to optimize the value of its generating facilities.
We are exposed to credit risk primarily through our power marketing activities. We use credit policies to manage credit risk, which includes utilizing an established credit approval process and monitoring counterparty limits.
Recently Adopted Accounting Pronouncements.
New accounting pronouncements are discussed in Note 1. Operations and Significant Accounting Policies.
Item 7A. Quantitative and Qualitative Disclosures about Market Risk
See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Market Risk for information related to quantitative and qualitative disclosure about market risk.
ALLETE, Inc. 2022 Form 10-K
56
Item 8. Financial Statements and Supplementary Data
See our Consolidated Financial Statements as of December 31, 2022 and 2021, and for the years ended December 31, 2022, 2021 and 2020, and supplementary data, which are indexed in Item 15(a).
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
Not applicable.
Item 9A. Controls and Procedures
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
As of December 31, 2022, evaluations were performed, under the supervision and with the participation of management, including our principal executive officer and principal financial officer, on the effectiveness of the design and operation of ALLETE’s disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934 (Exchange Act). Based upon those evaluations, our principal executive officer and principal financial officer have concluded that such disclosure controls and procedures are effective to provide assurance that information required to be disclosed in ALLETE’s reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.
Management’s Report on Internal Control Over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f) or 15d-15(f). Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the Internal Control – Integrated Framework (framework) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under the framework, our management concluded that our internal control over financial reporting was effective as of December 31, 2022.
The effectiveness of the Company’s internal control over financial reporting as of December 31, 2022, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report which is included herein.
On April 15, 2022, the Company completed the acquisition of New Energy. As a result, management has excluded New Energy from our assessment of internal control over financial reporting. New Energy is a wholly-owned subsidiary whose total assets and total revenues represent 1 percent and 5 percent, respectively, of the related Consolidated Financial Statement amounts as of and for the year ended December 31, 2022.
Changes in Internal Controls
There has been no change in our internal control over financial reporting that occurred during our most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
Item 9B. Other Information
Not applicable.
Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections
Not applicable.
ALLETE, Inc. 2022 Form 10-K
57
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES
Financial Statement Preparation. References in this report to “we,” “us,” and “our” are to ALLETE and its subsidiaries, collectively. We prepare our financial statements in conformity with GAAP. These principles require management to make informed judgments, best estimates, and assumptions that affect the reported amounts of assets, liabilities, revenue and expenses. Actual results could differ from those estimates. The presentation of certain prior period amounts on the Consolidated Financial Statements have been adjusted for comparative purposes.
Subsequent Events. The Company performed an evaluation of subsequent events for potential recognition and disclosure through the time of the financial statements issuance.
Principles of Consolidation. Our Consolidated Financial Statements include the accounts of ALLETE, all of our majority‑owned subsidiary companies and variable interest entities of which ALLETE is the primary beneficiary. All material intercompany balances and transactions have been eliminated in consolidation.
Variable Interest Entities. The accounting guidance for “Variable Interest Entities” (VIE) is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether ALLETE is the primary beneficiary of a VIE, management considers whether ALLETE has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. The accounting guidance for VIEs applies to certain ALLETE Clean Energy wind energy facilities and our investment in Nobles 2. (See Tax Equity Financing.)
Business Segments. We present two reportable segments: Regulated Operations and ALLETE Clean Energy. Our segments were determined in accordance with the guidance on segment reporting. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment.
Regulated Operations includes our regulated utilities, Minnesota Power and SWL&P, as well as our investment in ATC, a Wisconsin-based regulated utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. Minnesota Power provides regulated utility electric service in northeastern Minnesota to approximately 150,000 retail customers. Minnesota Power also has 14 non-affiliated municipal customers in Minnesota. SWL&P is a Wisconsin utility and a wholesale customer of Minnesota Power. SWL&P provides regulated utility electric, natural gas and water service in northwestern Wisconsin to approximately 15,000 electric customers, 13,000 natural gas customers and 10,000 water customers. Our regulated utility operations include retail and wholesale activities under the jurisdiction of state and federal regulatory authorities.
ALLETE Clean Energy focuses on developing, acquiring, and operating clean and renewable energy projects. ALLETE Clean Energy currently owns and operates, in seven states, more than 1,200 MW of nameplate capacity wind energy generation with a majority contracted under PSAs of various durations. In addition, ALLETE Clean Energy also engages in the development of wind energy facilities to operate under long-term PSAs or for sale to others upon completion. ALLETE Clean Energy currently has approximately 100 MW of wind energy facilities under contract to be sold to others.
ALLETE, Inc. 2022 Form 10-K
74
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Corporate and Other is comprised of New Energy, our investment in Nobles 2, South Shore Energy, BNI Energy, ALLETE Properties, other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, land holdings in Minnesota, and earnings on cash and investments.
New Energy is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services.
Our investment in Nobles 2 represents a 49 percent equity interest in Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20-year PPA with Minnesota Power.
South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary, is developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting in 2027 pursuant to a capacity dedication agreement. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $700 million, of which South Shore Energy’s portion is expected to be approximately $150 million. South Shore Energy’s portion of NTEC project costs incurred through December 31, 2022, is approximately $7 million.
BNI Energy mines and sells lignite coal to two North Dakota mine-mouth generating units, one of which is Square Butte. In 2022, Square Butte supplied 50 percent (227.5 MW) of its output to Minnesota Power under long-term contracts. (See Note 9. Commitments, Guarantees and Contingencies.)
ALLETE Properties represents our legacy Florida real estate investment. Our strategy incorporates the possibility of a bulk sale of the entire ALLETE Properties portfolio. Proceeds from a bulk sale would be strategically deployed to support growth at our Regulated Operations and ALLETE Clean Energy. ALLETE Properties continues to pursue sales of individual parcels over time and will continue to maintain key entitlements and infrastructure.
Cash, Cash Equivalents and Restricted Cash. We consider all investments purchased with original maturities of three months or less to be cash equivalents. As of December 31, 2022, and 2021, restricted cash amounts included in Prepayments and Other on the Consolidated Balance Sheet include collateral deposits required under an ALLETE Clean Energy loan agreement. The restricted cash amounts included in Other Non-Current Assets represent collateral deposits required under an ALLETE Clean Energy loan agreement and PSAs. The December 31, 2020 amount also includes deposits required under tax equity financing agreements. The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the Consolidated Balance Sheet that aggregate to the amounts presented in the Consolidated Statement of Cash Flows.
| | | | | | | | | | | | | | | | | |
| Cash, Cash Equivalents and Restricted Cash | | | | | |
| As of December 31 | 2022 | | 2021 | | 2020 |
| Millions | | | | | |
| Cash and Cash Equivalents | $36.4 | | | $45.1 | | | $44.3 | |
| Restricted Cash included in Prepayments and Other | 1.5 | | | 0.3 | | | 0.8 | |
| Restricted Cash included in Other Non-Current Assets | 2.3 | | | 2.3 | | | 20.1 | |
| Cash, Cash Equivalents and Restricted Cash on the Consolidated Statement of Cash Flows | $40.2 | | | $47.7 | | | $65.2 | |
ALLETE, Inc. 2022 Form 10-K
75
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Supplemental Statement of Cash Flow Information. | | | | | | | | | | | | |
| Consolidated Statement of Cash Flows | | | | |
| Year Ended December 31 | 2022 | 2021 | 2020 | |
| Millions | | | | |
| Cash Paid During the Period for Interest – Net of Amounts Capitalized | $72.8 | | $66.8 | | $62.0 | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Cash Paid (Received) for Income Taxes | $6.0 | | — | | $(2.0) | |
| Noncash Investing and Financing Activities | | | | |
| Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment | $(9.6) | $(14.0) | $(67.0) | |
Reclassification of Property, Plant and Equipment to Inventory (a) | $99.7 | | — | | — | | |
Reclassification of Redeemable Non-Controlling Interest to Current Liabilities (b) | — | | $30.6 | | — | | |
| Capitalized Asset Retirement Costs | $11.8 | | $16.9 | | $4.1 | | |
| | | | |
| | | | |
| AFUDC–Equity | $2.7 | | $2.6 | | $1.9 | | |
| | | | |
| | | | |
| | | | |
| | | | |
(a)The decommissioning of the existing Northern Wind assets resulted in a reclassification from Property, Plant and Equipment – Net to Inventories – Net in the second quarter of 2022 as they were repowered and subsequently sold to a subsidiary of Xcel Energy Inc. In the third quarter of 2022, safe harbor equipment was transferred to the project entity resulting in an additional reclassification from Property, Plant and Equipment – Net to Inventories – Net.
(b)Amount reclassified to Current Liabilities resulting from the exercise of an option to buy out a non-controlling interest.
Accounts Receivable. Accounts receivable are reported on the Consolidated Balance Sheet net of an allowance for doubtful accounts. The allowance is based on our evaluation of the receivable portfolio under current conditions, overall portfolio quality, review of specific situations and such other factors that, in our judgment, deserve recognition in estimating losses.
| | | | | | | | | | | |
| Accounts Receivable | | | |
| As of December 31 | 2022 | | 2021 |
| Millions | | | |
| Trade Accounts Receivable | | | |
| Billed | $107.1 | | | $100.6 | |
| Unbilled | 29.2 | | | 24.7 | |
| Less: Allowance for Doubtful Accounts | 1.6 | | | 1.8 | |
| Total Trade Accounts Receivable | 134.7 | | | 123.5 | |
| Income Taxes Receivable | 3.2 | | | 0.2 | |
| Total Accounts Receivable | $137.9 | | | $123.7 | |
Concentration of Credit Risk. We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to seven Large Power Customers. Receivables from these customers totaled $11.3 million as of December 31, 2022 ($7.8 million as of December 31, 2021). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2022, accounted for approximately 32 percent of Regulated Operations operating revenue and approximately 26 percent of consolidated operating revenue in 2022 (32 percent of Regulated Operations operating revenue and 28 percent of consolidated operating revenue in 2021 and 29 percent of Regulated Operations operating revenue and 25 percent of consolidated operating revenue in 2020).
Long-Term Finance Receivables. Long-term finance receivables relating to our real estate operations are collateralized by property sold, accrue interest at market-based rates and are net of an allowance for doubtful accounts. We assess delinquent finance receivables by comparing the balance of such receivables to the estimated fair value of the collateralized property. If the fair value of the property is less than the finance receivable, we record a reserve for the difference. We estimate fair value based on recent property tax assessed values or current appraisals.
ALLETE, Inc. 2022 Form 10-K
76
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Available-for-Sale Securities. Available-for-sale debt and equity securities are recorded at fair value. Unrealized gains and losses on available-for-sale debt securities are included in accumulated other comprehensive income (loss), net of tax. Unrealized gains and losses on available-for-sale equity securities are recognized in earnings. We use the specific identification method as the basis for determining the cost of securities sold.
Inventories – Net. Inventories are stated at the lower of cost or net realizable value. Inventories in our Regulated Operations segment are carried at an average cost or first-in, first-out basis. Inventories in our ALLETE Clean Energy segment and Corporate and Other businesses are carried at an average cost, first-in, first-out or specific identification basis.
| | | | | | | | | | | |
| Inventories – Net | | | |
| As of December 31 | 2022 | | 2021 |
| Millions | | | |
Fuel (a) | $33.4 | | | $18.7 | |
| Materials and Supplies | 75.1 | | | 56.1 | |
Construction of Wind Energy Facilities (b) | 347.4 | | | 22.9 | |
| | | |
| | | |
| | | |
| | | |
| Total Inventories – Net | $455.9 | | | $97.7 | |
(a) Fuel consists primarily of coal inventory at Minnesota Power.
(b) Project costs related to ALLETE Clean Energy’s Northern Wind project sold in January 2023 and Red Barn wind project which is expected to be sold in the first half 2023. (See Other Current Liabilities.)
Property, Plant and Equipment. Property, plant and equipment are recorded at original cost and are reported on the Consolidated Balance Sheet net of accumulated depreciation. Expenditures for additions, significant replacements, improvements and major plant overhauls are capitalized; maintenance and repair costs are expensed as incurred. Gains or losses on property, plant and equipment for Corporate and Other operations are recognized when they are retired or otherwise disposed. When property, plant and equipment in our Regulated Operations and ALLETE Clean Energy segments are retired or otherwise disposed, no gain or loss is recognized in accordance with the accounting standards for component depreciation except for certain circumstances where the retirement is unforeseen or unexpected. Our Regulated Operations capitalize AFUDC, which includes both an interest and equity component. AFUDC represents the cost of both debt and equity funds used to finance utility plant additions during construction periods. AFUDC amounts capitalized are included in rate base and are recovered from customers as the related property is depreciated. Upon MPUC approval of cost recovery, the recognition of AFUDC ceases. (See Note 2. Property, Plant and Equipment.)
We believe that long-standing ratemaking practices approved by applicable state and federal regulatory commissions allow for the recovery of the remaining book value of retired plant assets. The MPUC order for Minnesota Power’s 2015 IRP directed Minnesota Power to retire Boswell Units 1 and 2, which occurred in the fourth quarter of 2018. As part of the 2016 general retail rate case, the MPUC allowed recovery of the remaining book value of Boswell Units 1 and 2 through 2022. Minnesota Power’s latest IRP, which was approved by the MPUC in an order dated January 9, 2023, includes ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. Boswell Unit 3 and Unit 4 have a net book value of approximately $235 million and $435 million, respectively, as of December 31, 2022. (See Note 4. Regulatory Matters.) Minnesota Power’s latest IRP also includes the retirement of Taconite Harbor. As of December 31, 2022, Taconite Harbor had a net book value of approximately $25 million. We do not expect to record any impairment charge as a result of these operating changes at Taconite Harbor and Boswell. In addition, we expect to be able to continue depreciating these assets for at least their established remaining useful lives; however, we are unable to predict the impact of regulatory outcomes resulting in changes to their established remaining useful lives.
Impairment of Long-Lived Assets. We review our long-lived assets for indicators of impairment in accordance with the accounting standards for property, plant and equipment on a quarterly basis. This includes our property, plant and equipment (see Property, Plant and Equipment) and land inventory. Land inventory is accounted for as held for use and is recorded at cost, unless the carrying value is determined not to be recoverable in accordance with the accounting standards for property, plant and equipment, in which case the land inventory is written down to estimated fair value.
ALLETE, Inc. 2022 Form 10-K
77
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
In accordance with the accounting standards for property, plant and equipment, if indicators of impairment exist, we test our long‑lived assets for recoverability by comparing the carrying amount of the asset to the undiscounted future net cash flows expected to be generated by the asset. Cash flows are assessed at the lowest level of identifiable cash flows. The undiscounted future net cash flows are impacted by trends and factors known to us at the time they are calculated and our expectations related to: management’s best estimate of future use; sales prices; holding period and timing of sales; method of disposition; and future expenditures necessary to maintain the operations.
We continue to monitor changes in the broader energy markets along with wind resource expectations that could indicate impairment at ALLETE Clean Energy wind energy facilities upon contract expirations. A decline in energy prices or lower wind resource expectations could result in a future impairment.
In 2022 and 2021 there were triggering events that indicated an impairment for our property, plant, and equipment at certain ALLETE Clean Energy wind energy facilities with expiring PSAs for which a recoverability test was performed indicating that the undiscounted cash flows adequately supported the property, plant and equipment book values. As a result, no impairment was recorded in 2022 and 2021. In 2020, there were indicators of impairment for ALLETE Clean Energy’s Northern Wind project. See Immaterial Revision to Prior Period.
Immaterial Revision to Prior Period. We have identified an immaterial prior period error with respect to the recognition of a non-cash impairment expense for our Northern Wind operating assets in the fourth quarter of 2020 prior to the execution of the purchase and sales agreement for a repower and sale of the wind energy facility. Specifically, the remaining net book value of the property, plant and equipment used in the recoverability test was calculated incorrectly. If the net book value would have been calculated correctly in the recoverability test, an $8.8 million after-tax impairment expense would have been recognized in the fourth quarter of 2020. We evaluated the effects of this error on our previously-issued consolidated financial statements in accordance with the guidance in Accounting Standards Codification Topic (ASC) 250, Accounting Changes and Error Corrections, ASC 250-10-S99-1, Assessing Materiality, and ASC 250-10-S99-2, Considering the Effects of Prior Year Misstatements when Quantifying Misstatements in Current Year Financial Statements, and concluded that no prior period is materially misstated. Accordingly, we have revised our consolidated financial statements for the impacted prior periods herein.
A summary of the effect of the revision on the Consolidated Statements of Income and Consolidated Statement of Comprehensive Income for the year ended December 31, 2020 is as follows:
| | | | | | | | | | | | |
| Revision Impacts for the Year Ended December 31, 2020 | As Reported | Adjustment | As Revised | |
| Millions Except Per Share Amounts | | | | |
| | | | |
| Impairment of Property, Plant and Equipment | — | | $12.7 | | $12.7 | | |
| Income Tax Benefit | $(39.5) | (3.9) | (43.4) | |
| Net Income Attributable to ALLETE | $174.2 | | $(8.8) | $165.4 | | |
| | | | |
| Comprehensive Income Attributable to ALLETE | $166.7 | | $(8.8) | $157.9 | | |
| | | | |
| Diluted Earnings Per Share | $3.35 | | $(0.17) | $3.18 | | |
ALLETE, Inc. 2022 Form 10-K
78
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
A summary of the effect of the revision on the Consolidated Balance Sheet as of December 31, 2021 is as follows:
| | | | | | | | | | | | |
| Revision Impacts for the Year Ended December 31, 2021 | As Reported | Adjustment | As Revised | |
| Millions | | | | |
| | | | |
| Property, Plant and Equipment - Net | $5,100.2 | $(12.7) | $5,087.5 | |
| Total Assets | $6,435.0 | $(12.7) | $6,422.3 | |
| | | | |
| Deferred Income Taxes | $185.7 | $(3.9) | $181.8 | |
| Total Liabilities | $3,488.7 | $(3.9) | $3,484.8 | |
| | | | |
| Retained Earnings | $900.2 | $(8.8) | $891.4 | |
| Total Equity | $2,946.3 | $(8.8) | $2,937.5 | |
Derivatives. ALLETE is exposed to certain risks relating to its business operations that can be managed through the use of derivative instruments. ALLETE may enter into derivative instruments to manage those risks including interest rate risk related to certain variable-rate borrowings and commodity price risk related to sales to retail and municipal customers as well as other power suppliers. We have determined that either these agreements are not derivatives, or, if they are derivatives, the agreements qualify for the normal purchases and normal sales exception to derivative accounting guidance; therefore, derivative accounting is not required.
Accounting for Stock-Based Compensation. We apply the fair value recognition guidance for share-based payments. Under this guidance, we recognize stock-based compensation expense for all share-based payments granted, net of an estimated forfeiture rate. (See Note 13. Employee Stock and Incentive Plans.)
Goodwill. Goodwill is the excess of the purchase price (consideration transferred) over the estimated fair value of net assets of acquired businesses. In accordance with GAAP, goodwill is not amortized. Goodwill is assessed annually in the fourth quarter for impairment and whenever an event occurs or circumstances change that would indicate the carrying amount may be impaired. Impairment testing for goodwill is done at the reporting unit level.
As of the date of our annual goodwill impairment testing in 2022, the Company elected to bypass the qualitative assessment of goodwill for impairment, proceeding directly to the two-step impairment test for the New Energy reporting unit. In performing Step 1 of the impairment test, we compared the fair value of the reporting unit to its carrying value including goodwill. If the carrying value including goodwill were to exceed the fair value of a reporting unit, Step 2 of the impairment test would be performed. Step 2 of the impairment test requires the carrying value of goodwill to be reduced to its fair value, if lower, as of the test date.
For Step 1 of the impairment test, we estimated the reporting unit's fair value using standard valuation techniques, including techniques which use estimates of projected future results and cash flows to be generated by the reporting unit. Such techniques generally include a terminal value that utilizes a growth rate on debt-free cash flows. These cash flow valuations involve a number of estimates that require broad assumptions and significant judgment by management regarding future performance. Our annual impairment test in 2022 indicated that the estimated fair value of New Energy exceeded its carrying value, and therefore no impairment existed. The fair value of the reporting unit was determined using a discounted cash flow model, using significant assumptions which included a discount rate of 14 percent, cash flow forecasts through 2027, industry average gross margins, and a terminal growth rate of 3.5 percent.
ALLETE, Inc. 2022 Form 10-K
79
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
| | | | | | | | | | | |
| Other Non-Current Assets | | | |
| As of December 31 | 2022 | | 2021 |
| Millions | | | |
Contract Assets (a) | $21.0 | | | $23.3 | |
| | | |
| Operating Lease Right-of-use Assets | 12.7 | | | 16.4 | |
| ALLETE Properties | 19.1 | | | 19.4 | |
| Restricted Cash | 2.3 | | | 2.3 | |
| Other Postretirement Benefit Plans | 58.8 | | | 64.8 | |
| Other | 90.4 | | | 86.7 | |
| Total Other Non-Current Assets | $204.3 | | | $212.9 | |
(a) Contract Assets include payments made to customers as an incentive to execute or extend service agreements. The contract payments are being amortized over the term of the respective agreements as a reduction to revenue.
| | | | | | | | | | | |
| Other Current Liabilities | | | |
| As of December 31 | 2022 | | 2021 |
| Millions | | | |
Customer Deposits (a) | $150.7 | | | $27.2 | |
| PSAs | 6.1 | | | 12.6 | |
| | | |
| | | |
| Provision for Interim Rate Refund | 18.4 | | | — | |
Manufactured Gas Plant (b) | 14.7 | | | 12.8 | |
| Fuel Adjustment Clause | — | | | 5.0 | |
| Operating Lease Liabilities | 3.2 | | | 4.8 | |
Redeemable Non-Controlling Interest (c) | — | | | 30.6 | |
| Other | 57.9 | | | 40.0 | |
| Total Other Current Liabilities | $251.0 | | | $133.0 | |
(a) Primarily related to deposits received by ALLETE Clean Energy for the Northern Wind project sold in January 2023 and the Red Barn wind project which is expected to be sold in the first half of 2023. (See Inventories – Net.)
(b) The manufactured gas plant represents the current liability for remediation of a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. (See Note 9. Commitments, Guarantees and Contingencies.)
(c) Amount reclassified from Non-Controlling Interest in Subsidiaries resulting from the exercise of an option to buy out a non-controlling interest, which was paid in the first quarter of 2022.
| | | | | | | | | | | |
| Other Non-Current Liabilities | | | |
| As of December 31 | 2022 | | 2021 |
| Millions | | | |
Asset Retirement Obligation (a) | $200.4 | | | $184.5 | |
| PSAs | 26.9 | | | 39.5 | |
| Operating Lease Liabilities | 9.3 | | | 11.6 | |
| Other | 32.4 | | | 45.2 | |
| Total Other Non-Current Liabilities | $269.0 | | | $280.8 | |
(a) The asset retirement obligation is primarily related to our Regulated Operations and is funded through customer rates over the life of the related assets. Additionally, BNI Energy funds its obligation through its cost-plus coal supply agreements for which BNI Energy has recorded a receivable of $32.4 million in Other Non-Current Assets on the Consolidated Balance Sheet as of December 31, 2022 ($28.5 million as of December 31, 2021).
ALLETE, Inc. 2022 Form 10-K
80
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Leases. We determine if a contract is, or contains, a lease at inception and recognize a right-of-use asset and lease liability for all leases with a term greater than 12 months. Our right-of-use assets and lease liabilities for operating leases are included in Other Non-Current Assets, Other Current Liabilities and Other Non-Current Liabilities, respectively, in our Consolidated Balance Sheet. We currently do not have any finance leases.
Right-of-use assets represent our right to use an underlying asset for the lease term and lease liabilities represent the obligation to make lease payments arising from the lease. Operating lease right-of-use assets and lease liabilities are recognized at the commencement date based on the estimated present value of lease payments over the lease term. As our leases do not provide an explicit rate, we determine the present value of future lease payments based on our estimated incremental borrowing rate using information available at the lease commencement date. The operating lease right-of-use asset includes lease payments to be made during the lease term and any lease incentives, as applicable.
Our leases may include options to extend or buy out the lease at certain points throughout the term, and if it is reasonably certain at lease commencement that we will exercise that option, we include those rental payments in our calculation of the right-of-use asset and lease liability. Lease and rent expense is recognized on a straight-line basis over the lease term. Leases with a term of 12 months or less are not recognized on the Consolidated Balance Sheet.
The majority of our operating leases are for heavy equipment, vehicles and land with fixed monthly payments which we group into two categories: Vehicles and Equipment; and Land and Other. Our largest operating lease is for the dragline at BNI Energy which includes a termination payment at the end of the lease term if we do not exercise our purchase option. The amount of this payment is $3 million and is included in our calculation of the right-of-use asset and lease liability recorded. None of our other leases contain residual value guarantees.
Additional information on the components of lease cost and presentation of cash flows were as follows:
| | | | | | | | |
| As December 31 | 2022 | 2021 |
| Millions | | |
| Operating Lease Cost | $6.3 | | $6.7 | |
| | |
| Other Information: | | |
| Operating Cash Flows From Operating Leases | $6.3 | | $6.7 | |
| | |
Additional information related to leases was as follows: | | | | | | | | |
| As of December 31 | 2022 | 2021 |
| Millions | | |
| | |
| Balance Sheet Information Related to Leases: | | |
| Other Non-Current Assets | $12.7 | $16.4 |
| Total Operating Lease Right-of-use Assets | $12.7 | $16.4 |
| | |
| Other Current Liabilities | $3.2 | $4.8 |
| Other Non-Current Liabilities | 9.3 | 11.6 |
| Total Operating Lease Liabilities | $12.5 | $16.4 |
| | |
| Weighted Average Remaining Lease Term (Years): | | |
| Operating Leases - Vehicles and Equipment | 4 | 3 |
| Operating Leases - Land and Other | 16 | 27 |
| | |
| Weighted Average Discount Rate: | | |
| Operating Leases - Vehicles and Equipment | 3.9 | % | 3.8 | % |
| Operating Leases - Land and Other | 3.9 | % | 4.5 | % |
ALLETE, Inc. 2022 Form 10-K
81
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Maturities of lease liabilities were as follows:
| | | | | | | | |
| | | | December 31, 2022 |
| Millions | | | | |
| 2023 | | | | $3.4 | |
| 2024 | | | | 3.1 | |
| 2025 | | | | 2.9 | |
| 2026 | | | | 2.9 | |
| 2027 | | | | 3.8 | |
| Thereafter | | | | 1.2 | |
| Total Lease Payments Due | | | | 17.3 | |
| Less: Imputed Interest | | | | 4.8 | |
| Total Lease Obligations | | | | 12.5 | |
| Less: Current Lease Obligations | | | | 3.2 | |
| Total Long-term Lease Obligations | | | | $9.3 | |
Environmental Liabilities. We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated based on current law and existing technologies. Accruals are adjusted as assessment and remediation efforts progress, or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the Consolidated Balance Sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are expensed unless recoverable in rates from customers. (See Note 9. Commitments, Guarantees and Contingencies.)
Revenue.
Contracts with Customers – Utility includes sales from our regulated operations for generation, transmission and distribution of electric service, and distribution of water and gas services to our customers. Also included is an immaterial amount of regulated steam generation that is used by customers in the production of paper and pulp.
Contracts with Customers – Non-utility includes sales of goods and services to customers from ALLETE Clean Energy and our Corporate and Other businesses.
Other – Non-utility is the non-cash adjustments to revenue recognized by ALLETE Clean Energy for the amortization of differences between contract prices and estimated market prices for PSAs that were assumed during the acquisition of various wind energy facilities.
Revenue Recognition. Revenue is recognized upon transfer of control of promised goods or services to our customers in an amount that reflects the consideration we expect to receive in exchange for those products or services. Revenue is recognized net of allowance for returns and any taxes collected from customers, which are subsequently remitted to the appropriate governmental authorities. We account for shipping and handling activities that occur after the customer obtains control of goods as a cost rather than an additional performance obligation thereby recognizing revenue at time of shipment and accruing shipping and handling costs when control transfers to our customers. We have a right to consideration from our customers in an amount that corresponds directly with the value to the customer for our performance completed to date; therefore, we may recognize revenue in the amount to which we have a right to invoice.
ALLETE, Inc. 2022 Form 10-K
82
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Revenue (Continued)
Nature of Revenue Streams
Utility
Residential and Commercial includes sales for electric, gas or water service to customers, who have implied contracts with the utility, under rates governed by the MPUC, PSCW or FERC. Customers are billed on a monthly cycle basis and revenue is recognized for electric, gas or water service delivered during the billing period. Revenue is accrued for service provided but not yet billed at period end. Performance obligations with these customers are satisfied at time of delivery to customer meters and simultaneously consumed.
Municipal includes sales to 14 non-affiliated municipal customers in Minnesota under long-term wholesale electric contracts. One of these wholesale electric contracts include a termination clause requiring a three-year notice to terminate. These contracts have termination dates ranging through 2037, with a majority of contracts expiring in 2029. Performance obligations with these customers are satisfied at the time energy is delivered to an agreed upon municipal substation or meter.
Industrial includes sales recognized from contracts with customers in the taconite mining, paper, pulp and secondary wood products, pipeline and other industries. Industrial sales accounted for approximately 52 percent of total regulated utility kWh sales for the year ended December 31, 2022. Within industrial revenue, Minnesota Power had seven Large Power Customer contracts, each serving requirements of 10 MW or more of customer load as of December 31, 2022. These contracts automatically renew past the contract term unless a four-year written notice is given. Large Power Customer contracts have earliest termination dates ranging from 2026 through 2029. We satisfy our performance obligations for these customers at the time energy is delivered to an agreed upon customer substation. Revenue is accrued for energy provided but not yet billed at period end. Based on current contracts with industrial customers, we expect to recognize minimum revenue for the fixed contract components of approximately $55 million per annum through 2026, $15 million in 2027, and $25 million in total thereafter, which reflects the termination notice period in these contracts. When determining minimum revenue, we assume that customer contracts will continue under the contract renewal provision; however, if long-term contracts are renegotiated and subsequently approved by the MPUC or there are changes within our industrial customer class, these amounts may be impacted. Contracts with customers that contain variable pricing or quantity components are excluded from the expected minimum revenue amounts.
Other Power Suppliers includes the sale of energy under a long-term PSA with one customer as well as MISO market and liquidation sales. The expiration date of this PSA is 2028. Performance obligations with these customers are satisfied at the time energy is delivered to an agreed upon delivery point defined in the contract (generally the MISO pricing node). The current contract with one customer contains variable pricing components that prevent us from estimating future minimum revenue.
Other Revenue includes all remaining individually immaterial revenue streams for Minnesota Power and SWL&P, and is comprised of steam sales to paper and pulp mills, wheeling revenue and other sources. Revenue for steam sales to customers is recognized at the time steam is delivered and simultaneously consumed. Revenue is recognized at the time each performance obligation is satisfied.
CIP Financial Incentive reflects certain revenue that is a result of the achievement of certain objectives for our CIP financial incentives. This revenue is accounted for in accordance with the accounting standards for alternative revenue programs which allow for the recognition of revenue under an alternative revenue program if the program is established by an order from the utility’s regulatory commission, the order allows for automatic adjustment of future rates, the amount of revenue recognized is objectively determinable and probable of recovery, and the revenue will be collected within 24 months following the end of the annual period in which it is recognized. CIP financial incentives are recognized in the period in which the MPUC approves the filing, which is typically mid-year.
ALLETE, Inc. 2022 Form 10-K
83
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Revenue (Continued)
Non-utility
ALLETE Clean Energy
Long-term PSA revenue includes all sales recognized under long-term contracts for production, curtailment, capacity and associated renewable energy credits from ALLETE Clean Energy wind energy facilities. Expiration dates of these PSAs range from 2024 through 2039. Performance obligations for these contracts are satisfied at the time energy is delivered to an agreed upon point, or production is curtailed at the request of the customer, at specified prices. Revenue from the sale of renewable energy credits is recognized at the same time the related energy is delivered to the customer when sold to the same party.
Sale of Wind Energy Facility includes revenue recognized for the design, development, construction, and sale of a wind energy facility to a customer. Performance obligations for these types of agreements are satisfied at the time the completed project is transferred to the customer at the commercial operation date. Revenue from the sale of a wind energy facility is recognized at the time of asset transfer.
Other is the non-cash adjustments to revenue recognized by ALLETE Clean Energy for the amortization of differences between contract prices and estimated market prices on assumed PSAs. As part of wind energy facility acquisitions, ALLETE Clean Energy assumed various PSAs that were above or below estimated market prices at the time of acquisition; the resulting differences between contract prices and estimated market prices are amortized to revenue over the remaining PSA term.
Corporate and Other
Long-term Contract encompasses the sale and delivery of coal to customer generation facilities. Revenue is recognized on a monthly basis at the cost of production plus a specified profit per ton of coal delivered to the customer. Coal sales are secured under long-term coal supply agreements extending through 2037. Performance obligations are satisfied during the period as coal is delivered to customer generation facilities.
Sale of Renewable Development Projects includes revenue recognized from development only and development plus construction type projects that are sold to a customer. For development only projects, revenue is recognized at point in time when all required development responsibilities have been completed and ownership has transferred to the customer. For development plus construction, the transaction price is allocated to two performance obligations based upon the standalone selling price of each obligation. Revenue is recognized on the development performance obligation upon satisfying all required development activities and ownership transferring to the customer. Revenue for the construction performance obligation is recognized over time based on construction costs incurred, beginning at notice to proceed through the commercial operation date.
Other primarily includes revenue from BNI Energy unrelated to coal, revenue from New Energy for asset management services and non-development activities, the sale of real estate from ALLETE Properties, and non‑rate base steam generation that is sold for use during production of paper and pulp. Performance obligations are satisfied when control transfers to the customer.
Payment Terms. Payment terms and conditions vary across our businesses. Aside from taconite-producing Large Power Customers, payment terms generally require payment to be made within 15 to 30 days from the end of the period that the service has been rendered. In the case of its taconite-producing Large Power Customers, as permitted by the MPUC, Minnesota Power requires weekly payments for electric usage based on monthly energy usage estimates. These customers receive estimated bills based on Minnesota Power’s estimate of the customers’ energy usage, forecasted energy prices and fuel adjustment clause estimates. Minnesota Power’s taconite-producing Large Power Customers have generally predictable energy usage on a weekly basis and any differences that occur are trued-up the following month. Due to the timing difference of revenue recognition from the timing of invoicing and payment, the taconite-producing Large Power Customers receive credit for the time value of money; however, we have determined that our contracts do not include a significant financing component as the period between when we transfer the service to the customer and when they pay for such service is minimal.
ALLETE, Inc. 2022 Form 10-K
84
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Revenue (Continued)
Assets Recognized From the Costs to Obtain a Contract with a Customer. We recognize as an asset the incremental costs of obtaining a contract with a customer if we expect the benefit of those costs to be longer than one year. We expense incremental costs when the asset that would have resulted from capitalizing these costs would have been amortized in one year or less. As of December 31, 2022, we have $21.0 million of assets recognized for costs incurred to obtain contracts with our customers ($23.3 million as of December 31, 2021). Management determined the amount of costs to be recognized as assets based on actual costs incurred and paid to obtain and fulfill these contracts to provide goods and services to our customers. Assets recognized to obtain contracts are amortized on a straight-line basis over the contract term as a non-cash reduction to revenue. We recognized $2.4 million of non-cash amortization for the year ended December 31, 2022 ($2.7 million for the year end December 31, 2021).
Unamortized Discount and Premium on Debt. Discount and premium on debt are deferred and amortized over the terms of the related debt instruments using a method which approximates the effective interest method.
Tax Equity Financings. Certain subsidiaries of ALLETE have entered into tax equity financings that include forming limited liability companies (LLC) with third-party investors for certain wind projects. Tax equity financings have specific terms that dictate distributions of cash and the allocation of tax attributes among the LLC members, who are divided into two categories: the sponsor and third-party investors. ALLETE subsidiaries are the sponsors in these tax equity financings. The distributions of cash and allocation of tax attributes in these financings generally differ from the underlying ownership percentage interests in the related LLC, with a disproportionate share of tax attributes (including accelerated depreciation and production tax credits) allocated to third-party investors in order to achieve targeted after-tax rates of return, or target yield, from project operations, and a disproportionate share of cash distributions made to the sponsor.
The target yield and other terms vary by tax equity financing. Once the target yield has been achieved, a “flip point” is recognized. In addition, tax equity financings typically provide that cash distributions can be temporarily increased to the third-party investors in order to meet cumulative distribution thresholds. After the flip point, tax attributes and cash distributions are both typically disproportionately allocated to the sponsor.
Tax equity financings include affirmative and negative covenants that are similar to what a project lender would require in a project financing, such as financial reporting, insurance, maintenance and prudent operator standards. Most covenants are no longer applicable once the flip point occurs and any other obligations of the third-party investor have been eliminated.
The third-party investors’ portions of equity ownership in tax equity LLCs are recorded as non-controlling interest in subsidiaries on the Consolidated Balance Sheet and earnings allocated to third-party investors are recorded as net loss attributable to non-controlling interest on the Consolidated Statement of Income.
Non-Controlling Interest in Subsidiaries. Non-controlling interest in subsidiaries represents the portion of equity ownership, net income (loss), and comprehensive income (loss) in subsidiaries that is not attributable to equity holders of ALLETE. These amounts as of and for the years ended December 31, 2022 and 2021, related to the tax equity financings for ALLETE Clean Energy’s 106 MW Glen Ullin, 80 MW South Peak, 303 MW Diamond Spring and 303 MW Caddo wind energy facilities as well as ALLETE’s equity investment in the 250 MW Nobles 2 wind energy facility.
For those wind projects with tax equity financings where the economic benefits are not allocated based on the underlying ownership percentage interests, we have determined that the appropriate methodology for calculating the non-controlling interest in subsidiaries balance is the hypothetical liquidation at book value (HLBV) method. The HLBV method is a balance sheet approach which reflects the substantive economic arrangements in the tax equity financing structures.
Under the HLBV method, amounts reported as non-controlling interest in subsidiaries on the Consolidated Balance Sheet represent the amounts the third-party investors would hypothetically receive at each balance sheet reporting date under the liquidation provisions of the LLC agreements, assuming the net assets of the wind projects were liquidated at amounts determined in accordance with GAAP and distributed to the third-party investor and sponsor. The resulting non-controlling interest in subsidiaries balance in these projects is reported as a component of equity on the Consolidated Balance Sheet.
The results of operations for these projects attributable to non-controlling interest under the HLBV method is determined as the difference in non-controlling interest in subsidiaries on the Consolidated Balance Sheet at the start and end of each reporting period, after taking into account any capital transactions between the projects and the third-party investors.
ALLETE, Inc. 2022 Form 10-K
85
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Factors used in the HLBV calculation include GAAP income, taxable income (loss), tax attributes such as accelerated depreciation and production tax credits, capital contributions, cash distributions, and the target yield specified in the corresponding LLC agreement. Changes in these factors could have a significant impact on the amounts that third-party investors and sponsors would receive upon a hypothetical liquidation. The use of the HLBV method to allocate income to the non-controlling interest in subsidiaries may create variability in our results of operations as the application of the HLBV method can drive variability in net income or loss attributable to non-controlling interest in subsidiaries from period to period.
| | | | | | | | | | | |
| Other Income (Expense) - Other | | | |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Millions | | | |
Pension and Other Postretirement Benefit Plan Non-Service Credit (a) | $9.8 | | $6.1 | | $8.6 | |
| Interest and Investment Earnings | — | | 2.3 | | 1.6 | |
| AFUDC - Equity | 2.7 | | 2.6 | | 1.9 | |
| Gain on Land Sales | — | | 0.1 | | 0.4 | |
PSA Liability (b) | 10.2 | | — | | — | |
| Other | (0.3) | | (2.4) | | 2.2 | |
| Total Other Income (Expense) - Other | $22.4 | | $8.7 | | $14.7 | |
(a)These are components of net periodic pension and other postretirement benefit cost other than service cost. (See Note 12. Pension and Other Postretirement Benefit Plans.)
(b)The gain on removal of the PSA liability for the Northern Wind project upon decommissioning of the legacy wind energy facility assets, which was more than offset by a reserve for an anticipated loss on the sale of the Northern Wind project, was recorded in Cost of Sales - Non-Utility on the Consolidated Statement of Income.
Income Taxes. ALLETE and its subsidiaries file a consolidated federal income tax return as well as combined and separate state income tax returns. We account for income taxes using the liability method in accordance with GAAP for income taxes. Under the liability method, deferred income tax assets and liabilities are established for all temporary differences in the book and tax basis of assets and liabilities, based upon enacted tax laws and rates applicable to the periods in which the taxes become payable.
Due to the effects of regulation on Minnesota Power and SWL&P, certain adjustments made to deferred income taxes are, in turn, recorded as regulatory assets or liabilities. Tax credits are recorded when earned unless there is a requirement to defer the benefit and amortize it over the book depreciable lives of the related property. The requirement to defer and amortize tax credits only applies to federal credits related to public utility property. In accordance with GAAP for uncertainty in income taxes, we are required to recognize in our financial statements the largest tax benefit of a tax position that is “more‑likely‑than‑not” to be sustained on audit, based solely on the technical merits of the position as of the reporting date. The term “more‑likely‑than‑not” means more than 50 percent likely. (See Note 11. Income Tax Expense.)
Excise Taxes. We collect excise taxes from our customers levied by governmental entities. These taxes are stated separately on the billing to the customer and recorded as a liability to be remitted to the governmental entity. We account for the collection and payment of these taxes on a net basis.
ALLETE, Inc. 2022 Form 10-K
86
NOTE 2. PROPERTY, PLANT AND EQUIPMENT
| | | | | | | | | | | |
| Property, Plant and Equipment | | | |
| As of December 31 | 2022 | | 2021 |
| Millions | | | |
| Regulated Operations | | | |
| Property, Plant and Equipment in Service | $5,198.6 | | | $5,028.7 | |
| | | |
| Construction Work in Progress | 74.0 | | | 108.7 | |
| Accumulated Depreciation | (1,972.3) | | | (1,834.6) | |
| Regulated Operations – Net | 3,300.3 | | | 3,302.8 | |
| ALLETE Clean Energy | | | |
| Property, Plant and Equipment in Service | 1,619.4 | | | 1,704.2 | |
| Construction Work in Progress | 51.1 | | | 79.9 | |
| Accumulated Depreciation | (176.8) | | | (149.0) | |
| ALLETE Clean Energy – Net | 1,493.7 | | | 1,635.1 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
Corporate and Other (a) | | | |
| Property, Plant and Equipment in Service | 295.2 | | | 267.1 | |
| Construction Work in Progress | 50.9 | | | 19.8 | |
| Accumulated Depreciation | (136.1) | | | (137.3) | |
| Corporate and Other – Net | 210.0 | | | 149.6 | |
| Property, Plant and Equipment – Net | $5,004.0 | | | $5,087.5 | |
(a)Primarily includes BNI Energy and a small amount of non-rate base generation.
Depreciation is computed using the straight-line method over the estimated useful lives of the various classes of assets.
| | | | | | | | | | | | | | |
| Estimated Useful Lives of Property, Plant and Equipment (Years) |
| Regulated Operations | | | | |
| Generation | 1 to 50 | | ALLETE Clean Energy | 5 to 35 |
| Transmission | 50 to 75 | | Corporate and Other | 3 to 50 |
| Distribution | 18 to 70 | | | |
Asset Retirement Obligations. We recognize, at fair value, obligations associated with the retirement of certain tangible, long‑lived assets that result from the acquisition, construction, development or normal operation of the asset. Asset retirement obligations (AROs) relate primarily to the decommissioning of our coal-fired and wind energy facilities, and land reclamation at BNI Energy. AROs are included in Other Non-Current Liabilities on the Consolidated Balance Sheet. The associated retirement costs are capitalized as part of the related long-lived asset and depreciated over the useful life of the asset. Removal costs associated with certain distribution and transmission assets have not been recognized, as these facilities have indeterminate useful lives.
Conditional asset retirement obligations have been identified for treated wood poles and remaining polychlorinated biphenyl and asbestos-containing assets; however, the period of remediation is indeterminable and removal liabilities have not been recognized.
Long-standing ratemaking practices approved by applicable state and federal regulatory authorities have allowed provisions for future plant removal costs in depreciation rates. These plant removal cost recoveries are classified either as AROs or as a regulatory liability for non-AROs. To the extent annual accruals for plant removal costs differ from accruals under approved depreciation rates, a regulatory asset has been established in accordance with GAAP for AROs. (See Note 4. Regulatory Matters.)
ALLETE, Inc. 2022 Form 10-K
87
NOTE 2. PROPERTY, PLANT AND EQUIPMENT (Continued)
| | | | | | | | |
| Asset Retirement Obligations | | |
| Millions | | |
| Obligation as of December 31, 2020 | | $166.6 | |
| Accretion | | 8.8 | |
| Liabilities Recognized | | 4.5 | |
| Liabilities Settled | | (5.2) | |
| Revisions in Estimated Cash Flows | | 9.8 | |
| Obligation as of December 31, 2021 | | 184.5 | |
| Accretion | | 9.5 | |
| Liabilities Recognized | | 7.8 | |
| Liabilities Settled | | (4.4) | |
| Revisions in Estimated Cash Flows | | 3.0 | |
| Obligation as of December 31, 2022 | | $200.4 | |
NOTE 3. JOINTLY-OWNED FACILITIES AND ASSETS
Boswell Unit 4. Minnesota Power owns 80 percent of the 585 MW Boswell Unit 4. While Minnesota Power operates the plant, certain decisions about the operations of Boswell Unit 4 are subject to the oversight of a committee on which it and WPPI Energy, the owner of the remaining 20 percent, have equal representation and voting rights. Each owner must provide its own financing and is obligated to its ownership share of operating costs. Minnesota Power’s share of operating expenses for Boswell Unit 4 is included in Operating Expenses on the Consolidated Statement of Income.
Minnesota Power’s investments in jointly-owned facilities and assets and the related ownership percentages are as follows:
| | | | | | | | | | | | | | |
| Regulated Utility Plant | Plant in Service | Accumulated Depreciation | Construction Work in Progress | % Ownership |
| Millions | | | | |
| As of December 31, 2022 | | | | |
| Boswell Unit 4 | $712.0 | $340.1 | $3.3 | 80 |
| Transmission Assets | 101.0 | 21.1 | — | 9.3 - 14.7 |
| Total | $813.0 | $361.2 | $3.3 | |
| As of December 31, 2021 | | | | |
| Boswell Unit 4 | $682.7 | $311.1 | $30.1 | 80 |
| Transmission Assets | 101.0 | 18.5 | — | 9.3 - 14.7 |
| Total | $783.7 | $329.6 | $30.1 | |
ALLETE, Inc. 2022 Form 10-K
88
NOTE 4. REGULATORY MATTERS
Electric Rates. Entities within our Regulated Operations segment file for periodic rate revisions with the MPUC, PSCW or FERC. As authorized by the MPUC, Minnesota Power also recognizes revenue under cost recovery riders for transmission, renewable and environmental investments and expenditures. (See Transmission Cost Recovery Rider, Renewable Cost Recovery Rider, Solar Cost Recovery Rider and Environmental Improvement Rider.) Revenue from cost recovery riders was $38.8 million in 2022 ($38.9 million in 2021; $29.9 million in 2020).
Minnesota Retail Rates. Minnesota Power’s retail rates through 2021 were based on a 2018 MPUC retail rate order that allowed for a 9.25 percent return on common equity and a 53.81 percent equity ratio. The resolution of Minnesota Power’s 2020 general rate case did not change the allowed return on equity or equity ratio. (See 2020 Minnesota General Rate Case.)
2020 Minnesota General Rate Case. In November 2019, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 10.6 percent for retail customers. In December 2019 orders, the MPUC accepted the filing as complete and authorized an annual interim rate increase of $36.1 million beginning January 1, 2020.
In April 2020, Minnesota Power filed a request with the MPUC that proposed a resolution of Minnesota Power’s 2020 general rate case. Key components of our proposal included removing the power marketing margin credit in base rates and reflecting actual power marketing margins in the fuel adjustment clause effective May 1, 2020; refunding to customers interim rates collected through April 2020; increasing customer rates 4.1 percent compared to the 5.8 percent increase reflected in interim rates; and a provision that Minnesota Power would not file another rate case until at least November 1, 2021, unless certain events occur. In a June 2020 order, the MPUC approved Minnesota Power’s petition and proposal to resolve and withdraw the general rate case. Effective May 1, 2020, customer rates were set at an increase of 4.1 percent with the removal of the power marketing margin credit from base rates. Actual power marketing margins are now reflected in the fuel adjustment clause. Reserves for interim rates of $11.7 million were recorded in the second quarter of 2020 and refunded in the third and fourth quarters of 2020.
2022 Minnesota General Rate Case. On November 1, 2021, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 18 percent for retail customers. The rate filing seeks a return on equity of 10.25 percent and a 53.81 percent equity ratio. On an annualized basis, the requested final rate increase would generate approximately $108 million in additional revenue. In orders dated December 30, 2021, the MPUC accepted the filing as complete and authorized an annual interim rate increase beginning January 1, 2022, with approximately $80 million expected to be collected in cash and approximately $8 million of interim rates for residential customers deferred with a final determination on recovery at the end of the rate case.
At a hearing on January 23, 2023, the MPUC made determinations regarding Minnesota Power’s general rate case including allowing a return on common equity of 9.65 percent and a 52.50 percent equity ratio. Upon commencement of final rates, we expect additional revenue from base rates of approximately $60 million and an additional $10 million in revenue recognized under cost recovery riders on an annualized basis, subject to final written order and reconsideration. Final rates are expected to commence in the third quarter of 2023; interim rates will be collected through this period with reserves recorded as necessary. As a result of the MPUC’s determinations made on January 23, 2023, Minnesota Power has recorded a reserve for an interim rate refund of approximately $18 million pre-tax as of December 31, 2022, which is subject to MPUC approval of Minnesota Power’s refund calculation. In addition, Minnesota Power recorded a charge of approximately $8 million pre-tax to write-off the deferred portion of residential customer interim rates. Minnesota Power also recorded additional revenue of approximately $9 million pre-tax for an increase in expected recoveries under its cost recovery riders. Impacts of regulatory outcomes that are determined subsequent to the balance sheet date, and prior to issuance of the financial statements, are recognized in the financial statements as of the balance sheet date.
FERC-Approved Wholesale Rates. Minnesota Power has wholesale contracts with 14 non-affiliated municipal customers in Minnesota and SWL&P. Two of the wholesale contracts include a termination clause requiring a three-year notice to terminate.
Minnesota Power’s wholesale electric contract with the Nashwauk Public Utilities Commission is effective through December 31, 2037. The wholesale electric service contract with SWL&P is effective through February 28, 2026. Under the agreement with SWL&P, no termination notice has been given. The rates included in these two contracts are set each July 1 based on a cost-based formula methodology, using estimated costs and a rate of return that is equal to Minnesota Power’s authorized rate of return for Minnesota retail customers. The formula-based rate methodology also provides for a yearly true-up calculation for actual costs incurred.
ALLETE, Inc. 2022 Form 10-K
89
NOTE 4. REGULATORY MATTERS (Continued)
Electric Rates (Continued)
Minnesota Power’s wholesale electric contracts with 13 other municipal customers were extended in January 2022 and are effective through 2029. These contracts are based on fixed prices for capacity and energy. The base energy charge for each year is adjusted annually for updated fuel and purchased power costs.
Transmission Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for certain transmission investments and expenditures, including a return on the capital invested. Current customer billing rates are based on an MPUC order dated December 27, 2022, which provisionally approved Minnesota Power’s latest transmission factor filing submitted on October 31, 2022.
Renewable Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for the costs of certain renewable investments and expenditures, including a return on the capital invested. Current customer billing rates for the renewable cost recovery rider were approved by the MPUC in a 2020 order. On February 2, 2022, Minnesota Power submitted its latest renewable factor filing, which included a request to recover a regulatory asset of $3.8 million related to the recognition of production tax credits due to a metering error at Bison. The filing was approved in an order dated January 24, 2023 authorizing Minnesota Power to include updated billing rates on customer bills for recovery of the regulatory asset.
Solar Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for solar costs related to investments and expenditures for meeting the state of Minnesota’s solar energy standard. Current customer billing rates for the solar cost recovery rider were approved by the MPUC in an order dated August 31, 2022.
Electric Vehicle Charging Infrastructure Petition. In April 2021, Minnesota Power filed a petition seeking approval to install and own DC fast charger stations for electric vehicles across its service territory, implement accompanying rates for those stations, and track and recover investments and expenses for the project. In an October 2021 order, the MPUC approved Minnesota Power’s petition.
Fuel Adjustment Clause. In 2020, Minnesota Power filed its fuel adjustment forecast for 2021, which was approved by the MPUC in a December 2020 order, subject to the annual prudence review and true-up filing in 2022. During 2021, Minnesota Power incurred higher fuel and purchased power costs than those forecasted in its May 2020 filing, which resulted in the recognition of an approximately $56 million regulatory asset through December 31, 2021. Minnesota Power submitted its annual true-up filing and a significant events filing in March 2022 requesting recovery of these under-collected fuel adjustment clause recoveries. The MPUC approved recovery of the regulatory asset in an order dated July 5, 2022; recovery of the regulatory asset will continue through mid-2023.
Minnesota Power also incurred higher fuel and purchased power costs in 2022 than those factored in its fuel adjustment forecast filed in May 2021 for 2022, which resulted in the recognition of an approximately $13 million regulatory asset as of December 31, 2022. Minnesota Power filed a significant events filing in June 2022 requesting to increase rates from August 2022 through December 2022 in order to recover the under-collected fuel adjustment clause recoveries that were expected for 2022. No parties objected to the request and higher rates were implemented in August 2022. Minnesota Power will request recovery of the remaining regulatory asset as part of its annual true-up filing expected to be submitted to the MPUC in March 2023.
In 2020, Minnesota Power filed its FAC report covering the period July 2018 through December 2019. In a 2020 order, the MPUC referred the review of Minnesota Power’s forced outage costs during the period of the report, which totaled approximately $8 million, to an administrative law judge (ALJ) for a contested case hearing to recommend to the MPUC if any of those costs should be returned to customers. On August 11, 2021, the ALJ recommended that Minnesota Power refund approximately $5 million to ratepayers. Minnesota Power submitted exceptions to the ALJ’s report to the MPUC stating that it disagreed with the ALJ’s recommendation and that no refund should be made as the Company operated its facilities in accordance with good utility practice. At a hearing on January 13, 2022, the MPUC agreed with the ALJ’s recommendation and ordered the refund of approximately $5 million to ratepayers, which was recorded as a reserve as of December 31, 2021, and refunded to customers in 2022.
Wisconsin Retail Rates. SWL&P’s retail rates through 2022 were based on a December 2018 order by the PSCW that allowed for a return on equity of 10.4 percent and a 55.0 percent equity ratio.
ALLETE, Inc. 2022 Form 10-K
90
NOTE 4. REGULATORY MATTERS (Continued)
Electric Rates (Continued)
2022 Wisconsin General Rate Case. In 2022, SWL&P filed a rate increase request with the PSCW seeking an average increase of 3.6 percent for retail customers. The filing sought an overall return on equity of 10.4 percent and a 55 percent equity ratio. On an annualized basis, the requested final rate increase would have generated an estimated $4.3 million in additional revenue. In an order dated December 20, 2022, the PSCW approved an annual increase of $3.3 million reflecting a return on equity of 10.0 percent and 55 percent equity ratio. Final rates went into effect January 1, 2023.
Integrated Resource Plan. On February 1, 2021, Minnesota Power filed its latest IRP, which was approved by the MPUC in an order dated January 9, 2023. The approved IRP, which reflects a joint agreement reached with various stakeholders, outlines Minnesota Power’s clean-energy transition plans through 2035. These plans include expanding its renewable energy supply, achieving coal-free operations at its facilities by 2035, and investing in a resilient and flexible transmission and distribution grid. As part of these plans, Minnesota Power anticipates adding up to 700 MW of new wind and solar energy resources, and ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. Minnesota Power’s plans recognize that advances in technology will play a significant role in completing its transition to carbon-free energy supply, reliably and affordably. Minnesota Power is expected to file its next IRP by March 1, 2025.
Conservation Improvement Program. Minnesota requires electric utilities to spend a minimum of 1.5 percent of gross operating revenues, excluding revenue received from exempt customers, from service provided in the state on energy CIPs each year.
On April 1, 2022, Minnesota Power submitted its 2021 consolidated filing detailing Minnesota Power’s CIP program results and proposed CIP financial incentive, which was approved by the MPUC in an order dated July 5, 2022. As a result, Minnesota Power recognized revenue of $1.9 million in 2022 for the approved CIP financial incentive ($2.4 million in 2021 and $2.4 million in 2020). CIP financial incentives are recognized in the period in which the MPUC approves the filing.
In 2020, Minnesota Power submitted its CIP triennial filing for 2021 through 2023 to the MPUC and Minnesota Department of Commerce, which outlines Minnesota Power’s CIP spending and energy-saving goals for those years. Minnesota Power’s CIP investment goal is $10.9 million for 2023.
MISO Return on Equity Complaint. MISO transmission owners, including ALLETE and ATC, have an authorized return on equity of 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization based on a 2020 FERC order which is subject to various outstanding legal challenges related to the return on equity calculation and refund period ordered by the FERC. On August 9, 2022, the U.S. Court of Appeals for the District of Columbia Circuit vacated and remanded the 2020 FERC order back to the FERC. We cannot predict the return on equity the FERC will ultimately authorize in the remanded proceeding. (See Note 6. Equity Investments.)
Minnesota Solar Energy Standard. Minnesota law requires at least 1.5 percent of total retail electric sales, excluding sales to certain customers, to be generated by solar energy. At least 10 percent of the 1.5 percent mandate must be met by solar energy generated by or procured from solar photovoltaic devices with a nameplate capacity of 40 kW or less and community solar garden subscriptions. Minnesota Power has met both parts of the solar mandate to date.
In June 2020, Minnesota Power filed proposal with the MPUC to accelerate its plans for purchasing solar energy from approximately 20 MW of solar energy projects in Minnesota which was approved in a June 2021 order. These solar energy projects will be constructed and owned through an ALLETE subsidiary with an estimated investment of $40 million. Construction of these solar energy projects commenced in 2022 with a portion of these projects placed into service in the fourth quarter of 2022; the remaining project is expected to be placed into service in 2023.
Regulatory Assets and Liabilities. Our regulated utility operations are subject to accounting standards for the effects of certain types of regulation. Regulatory assets represent incurred costs that have been deferred as they are probable for recovery in customer rates. Regulatory liabilities represent obligations to make refunds to customers and amounts collected in rates for which the related costs have not yet been incurred. The Company assesses quarterly whether regulatory assets and liabilities meet the criteria for probability of future recovery or deferral. With the exception of the regulatory asset for Boswell Units 1 and 2 net plant and equipment, no other regulatory assets are currently earning a return. The recovery, refund or credit to rates for these regulatory assets and liabilities will occur over the periods either specified by the applicable regulatory authority or over the corresponding period related to the asset or liability.
ALLETE, Inc. 2022 Form 10-K
91
NOTE 4. REGULATORY MATTERS (Continued)
| | | | | | | | |
| Regulatory Assets and Liabilities | | |
| As of December 31 | 2022 | 2021 |
| Millions | | |
Current Regulatory Assets (a) | | |
Fuel Adjustment Clause (b) | $25.6 | | — | |
| Total Current Regulatory Assets | $25.6 | | — | |
| Non-Current Regulatory Assets | | |
| | |
Defined Benefit Pension and Other Postretirement Benefit Plans (c) | $225.9 | | $226.4 | |
| | |
Income Taxes (d) | 97.6 | | 104.7 | |
Cost Recovery Riders (e) | 41.2 | | 63.2 | |
Asset Retirement Obligations (f) | 35.6 | | 33.1 | |
Manufactured Gas Plant (g) | 15.1 | | 17.0 | |
Fuel Adjustment Clause (b) | 14.5 | | 56.4 | |
| PPACA Income Tax Deferral | 4.1 | | 4.3 | |
| | |
| | |
| Other | 7.0 | | 6.7 | |
| Total Non-Current Regulatory Assets | $441.0 | | $511.8 | |
| | |
| | |
Current Regulatory Liabilities (h) | | |
| Provision for Interim Rate Refund | $18.4 | | — | |
Fuel Adjustment Clause (b) | — | | $5.0 | |
| | |
| Transmission Formula Rates | 4.9 | | 3.1 | |
| Other | 0.1 | | 0.5 | |
| Total Current Regulatory Liabilities | $23.4 | | $8.6 | |
| Non-Current Regulatory Liabilities | | |
| | |
Income Taxes (d) | $332.5 | | $353.4 | |
Wholesale and Retail Contra AFUDC (j) | 80.7 | | 83.7 | |
Plant Removal Obligations (k) | 60.0 | | 52.6 | |
| | |
Defined Benefit Pension and Other Postretirement Benefit Plans (c) | 17.6 | | 28.1 | |
North Dakota Investment Tax Credits (l) | 16.9 | | 12.2 | |
Boswell Units 1 and 2 Net Plant and Equipment (i) | 6.7 | | 0.4 | |
Non-Jurisdictional Land Sales (m) | 7.5 | | — | |
| | |
| | |
| Other | 4.2 | | 5.7 | |
| Total Non-Current Regulatory Liabilities | $526.1 | | $536.1 | |
| | |
(a)Current regulatory assets are presented within Prepayments and Other on the Consolidated Balance Sheet.
(b)Fuel adjustment clause regulatory asset and liability represent the amount expected to be recovered from or refunded to customers for the under- or over-collection of fuel adjustment clause recoveries. (See Fuel Adjustment Clause.)
(c)Defined benefit pension and other postretirement items included in our Regulated Operations, which are otherwise required to be recognized in accumulated other comprehensive income, are recognized as regulatory assets or regulatory liabilities on the Consolidated Balance Sheet. The asset or liability will decrease as the deferred items are amortized and recognized as components of net periodic benefit cost. (See Note 12. Pension and Other Postretirement Benefit Plans.)
(d)These costs represent the difference between deferred income taxes recognized for financial reporting purposes and amounts previously billed to our customers. The balances will primarily decrease over the remaining life of the related temporary differences.
(e)The cost recovery rider regulatory assets and liabilities are revenue not yet collected from our customers and cash collections from our customers in excess of the revenue recognized, respectively, primarily due to capital expenditures related to Bison and the GNTL as well as differences between production tax credits recognized and those assumed in Minnesota Power’s base rates. The cost recovery rider regulatory assets as of December 31, 2022, will be recovered within the next two years.
(f)Asset retirement obligations will accrete and be amortized over the lives of the related property with asset retirement obligations.
(g)This regulatory asset represents costs of remediation for a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. We expect recovery of these remediation costs to be allowed by the PSCW in rates over time.
(h)Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet.
(i)In 2018, Minnesota Power retired Boswell Units 1 and 2 and reclassified the remaining net book value from property, plant and equipment to a regulatory asset on the Consolidated Balance Sheet. The remaining net book value is currently included in Minnesota Power’s rate base and Minnesota Power is earning a return on the outstanding balance.
(j)Wholesale and retail contra AFUDC represents amortization to offset AFUDC Equity and Debt recorded during the construction period of our cost recovery rider projects prior to placing the projects in service. The regulatory liability will decrease over the remaining depreciable life of the related asset.
(k)Non-legal plant removal obligations included in retail customer rates that have not yet been incurred.
(l)North Dakota investment tax credits expected to be realized from Bison that will be credited to Minnesota Power’s retail customers through future renewable cost recovery rider filings as the tax credits are utilized.
(m)This regulatory liability represents the net proceeds from the sale of certain land by Minnesota Power that is expected to be refunded to ratepayers through a future rate case or through its renewable resources rider.
ALLETE, Inc. 2022 Form 10-K
92
NOTE 5. ACQUISITIONS
2022 Activity
New Energy. On April 15, 2022, a wholly-owned subsidiary of ALLETE acquired 100 percent of the membership interests of New Energy for a purchase price of $165.5 million. Total consideration of approximately $158.8 million was paid in cash on the acquisition date, which is net of cash acquired and debt assumed. New Energy, which is headquartered in Annapolis, Maryland, is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. The acquisition of New Energy is consistent with ALLETE’s stated strategy of additional investment in renewable energy and related infrastructure across North America to support the Company’s sustainability-in-action strategy while providing potential long-term earnings growth.
The acquisition was accounted for as a business combination and the purchase price was allocated based on the estimated fair values of the assets acquired and the liabilities assumed at the date of acquisition. The allocation of the purchase price, which was finalized in the fourth quarter of 2022, is shown in the following table. Fair value measurements were valued primarily using the discounted cash flow method and replacement cost basis. The goodwill recorded is primarily attributable to the highly skilled workforce of New Energy and synergies expected to arise as a result of the acquisition.
Since the acquisition in April 2022, aggregate revenue was $80.2 million. The Company has not presented separate results of operations since closing or combined pro forma financial information of the Company and New Energy since the beginning of 2021, as the results of operations for New Energy are not material to the Company's consolidated financials.
| | | | | | | | |
| Millions | | | | |
| Assets Acquired | | | | |
| Cash and Cash Equivalents | | | | $3.9 | |
| Accounts Receivable | | | | 1.4 | |
Inventory (a) | | | | 25.3 | |
| Other Current Assets | | | | 12.8 | |
| Property, Plant and Equipment - Net | | | | 16.4 | |
Goodwill (b) | | | | 154.9 | |
| Other Non-Current Assets | | | | 2.1 | |
| Total Assets Acquired | | | | $216.8 | |
| Liabilities Assumed | | | | |
| Current Liabilities | | | | $23.6 | |
| Long-Term Debt Due Within One Year | | | | 28.3 | |
| Long-Term Debt | | | | 5.9 | |
| Other Non-Current Liabilities | | | | 0.2 | |
| Total Liabilities Assumed | | | | $58.0 | |
| Net Identifiable Assets Acquired | | | | $158.8 | |
(a)Includes $11.6 million of purchase price accounting for certain projects under development at the time of acquisition.
(b)For tax purpose, the purchase price allocation resulted in $154.9 million of deductible goodwill.
Acquisition-related costs were $2.7 million after-tax, expensed as incurred during 2022 and recorded in Operating and Maintenance on the Consolidated Statement of Income.
ALLETE, Inc. 2022 Form 10-K
93
NOTE 6. EQUITY INVESTMENTS
Investment in ATC. Our wholly-owned subsidiary, ALLETE Transmission Holdings, owns approximately 8 percent of ATC, a Wisconsin-based utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. We account for our investment in ATC under the equity method of accounting. On January 31, 2023, we invested an additional $0.8 million in ATC. In total, we expect to invest approximately $8.2 million in 2023.
| | | | | | | | |
| ALLETE’s Investment in ATC | | |
| Year Ended December 31 | 2022 | 2021 |
| Millions | | |
| Equity Investment Beginning Balance | $154.5 | | $149.0 | |
| Cash Investments | 5.9 | | — | |
| Equity in ATC Earnings | 19.3 | | 21.3 | |
| Distributed ATC Earnings | (15.5) | | (17.2) | |
| | |
| Amortization of the Remeasurement of Deferred Income Taxes | 1.2 | | 1.4 | |
| Equity Investment Ending Balance | $165.4 | | $154.5 | |
| | | | | | | | |
| ATC Summarized Financial Data | | |
| Balance Sheet Data | | |
| As of December 31 | 2022 | 2021 |
| Millions | | |
| Current Assets | $89.6 | | $89.8 | |
| Non-Current Assets | 5,997.8 | | 5,628.1 | |
| Total Assets | $6,087.4 | | $5,717.9 | |
| Current Liabilities | $511.9 | | $436.9 | |
| Long-Term Debt | 2,613.0 | | 2,513.0 | |
| Other Non-Current Liabilities | 485.8 | | 422.0 | |
| Members’ Equity | 2,476.7 | | 2,346.0 | |
| Total Liabilities and Members’ Equity | $6,087.4 | | $5,717.9 | |
| | | | | | | | | | | |
| Income Statement Data | | | |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Millions | | | |
| Revenue | $751.2 | | $754.8 | | $758.1 | |
| Operating Expense | 381.5 | | 376.2 | | 372.4 | |
| Other Expense | 122.9 | | 113.9 | | 110.9 | |
| Net Income | $246.8 | | $264.7 | | $274.8 | |
| ALLETE’s Equity in Net Income | $19.3 | | $21.3 | | $22.3 | |
ATC’s authorized return on equity is 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization, based on a 2020 FERC order which is subject to various outstanding legal challenges related to the return on equity calculation and refund period ordered by the FERC. On August 9, 2022, the U.S. Court of Appeals for the District of Columbia Circuit vacated and remanded the 2020 FERC order back to FERC. As a result of this decision, ATC recorded a reserve in the third quarter of 2022 for anticipated refunds to its customers for approximately $31 million of which our share was approximately $2.4 million pre-tax. We cannot predict the return on equity FERC will ultimately authorize in the remanded proceeding.
In addition, the FERC issued a Notice of Proposed Rulemaking in April 2021 proposing to limit the 50 basis point incentive adder for participation in a regional transmission organization to only the first three years of membership in such an organization. If this proposal is adopted, our equity in earnings from ATC would be reduced by approximately $1 million pre-tax annually.
ALLETE, Inc. 2022 Form 10-K
94
NOTE 6. EQUITY INVESTMENTS (Continued)
Investment in Nobles 2. Our subsidiary, ALLETE South Wind, owns a 49 percent equity interest in Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20-year PPA with Minnesota Power. We account for our investment in Nobles 2 under the equity method of accounting.
| | | | | | |
| ALLETE’s Investment in Nobles 2 | | |
| Millions | | |
| Equity Investment Balance as of December 31, 2021 | $163.5 | | |
| | |
Equity in Nobles 2 Earnings (a) | (0.6) | | |
| Distributed Nobles 2 Earnings | (5.6) | | |
| Equity Investment Balance as of December 31, 2022 | $157.3 | | |
(a)The Company also recorded net loss attributable to non-controlling interest of $10.6 million related to its investment in Nobles 2.
NOTE 7. FAIR VALUE
Fair value is 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 (exit price). We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. We primarily apply the market approach for recurring fair value measurements and endeavor to utilize the best available information. Accordingly, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. These inputs, which are used to measure fair value, are prioritized through the fair value hierarchy. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows:
Level 1 — Quoted prices are available in active markets for identical assets or liabilities as of the reported date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes primarily equity securities.
Level 2 — Pricing inputs are other than quoted prices in active markets, but are either directly or indirectly observable as of the reported date. The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts, such as treasury securities with pricing interpolated from recent trades of similar securities, or priced with models using highly observable inputs, such as commodity options priced using observable forward prices and volatilities. This category includes deferred compensation and fixed income securities.
Level 3 — Significant inputs that are generally less observable from objective sources. The types of assets and liabilities included in Level 3 are those with inputs requiring significant management judgment or estimation, such as the complex and subjective models and forecasts used to determine the fair value.
ALLETE, Inc. 2022 Form 10-K
95
NOTE 7. FAIR VALUE (Continued)
The following tables set forth by level within the fair value hierarchy, our assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2022, and December 31, 2021. Each asset and liability is classified based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of these assets and liabilities and their placement within the fair value hierarchy levels. The estimated fair value of Cash and Cash Equivalents listed on the Consolidated Balance Sheet approximates the carrying amount and therefore is excluded from the recurring fair value measures in the following tables. | | | | | | | | | | | | | | | | | | | | | | | |
| | Fair Value as of December 31, 2022 |
| Recurring Fair Value Measures | Level 1 | | Level 2 | | Level 3 | | Total |
| Millions | | | | | | | |
| Assets: | | | | | | | |
Investments (a) | | | | | | | |
| Available-for-sale – Equity Securities | $7.7 | | — | | — | | $7.7 |
Available-for-sale – Corporate and Governmental Debt Securities (b) | — | | $5.7 | | — | | 5.7 |
| Cash Equivalents | 4.2 | | — | | — | | 4.2 |
| Total Fair Value of Assets | $11.9 | | $5.7 | | — | | $17.6 |
| | | | | | | |
| Liabilities: | | | | | | | |
Deferred Compensation (c) | — | | $15.0 | | — | | $15.0 |
| | | | | | | |
| Total Fair Value of Liabilities | — | | $15.0 | | — | | $15.0 |
| | | | | | | |
(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.
(b)As of December 31, 2022, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $0.7 million, in one year to less than three years was $2.7 million, in three years to less than five years was $1.9 million and in five or more years was $0.4 million.
(c)Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.
| | | | | | | | | | | | | | | | | | | | | | | |
| | Fair Value as of December 31, 2021 |
| Recurring Fair Value Measures | Level 1 | | Level 2 | | Level 3 | | Total |
| Millions | | | | | | | |
| Assets: | | | | | | | |
Investments (a) | | | | | | | |
| Available-for-sale – Equity Securities | $8.9 | | — | | — | | $8.9 |
| Available-for-sale – Corporate and Governmental Debt Securities | — | | $6.2 | | — | | 6.2 |
| Cash Equivalents | 2.5 | | — | | — | | 2.5 |
| Total Fair Value of Assets | $11.4 | | $6.2 | | — | | $17.6 |
| | | | | | | |
Liabilities: (b) | | | | | | | |
| Deferred Compensation | — | | $18.0 | | — | | $18.0 |
| | | | | | | |
| Total Fair Value of Liabilities | — | | $18.0 | | — | | $18.0 |
| | | | | | | |
(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.
(b)Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.
The Company’s policy is to recognize transfers in and transfers out of levels as of the actual date of the event or change in circumstances that caused the transfer. For the years ended December 31, 2022 and 2021, there were no transfers in or out of Levels 1, 2 or 3.
Fair Value of Financial Instruments. With the exception of the item listed in the following table, the estimated fair value of all financial instruments approximates the carrying amount. The fair value for the item listed in the following table was based on quoted market prices for the same or similar instruments (Level 2).
ALLETE, Inc. 2022 Form 10-K
96
NOTE 7. FAIR VALUE (Continued)
| | | | | | | | | | | |
| Financial Instruments | Carrying Amount | | Fair Value |
| Millions | | | |
Short-Term and Long-Term Debt (a) | | | |
| December 31, 2022 | $1,929.1 | | $1,782.7 |
| December 31, 2021 | $1,986.4 | | $2,192.6 |
(a) Excludes unamortized debt issuance costs.
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis. Non-financial assets such as equity method investments, goodwill, intangible assets, and property, plant and equipment are measured at fair value when there is an indicator of impairment and recorded at fair value only when an impairment is recognized.
Equity Method Investments. The aggregate carrying amount of our equity investments was $322.7 million as of December 31, 2022 ($318.0 million as of December 31, 2021). The Company assesses our equity investments in ATC and Nobles 2 for impairment whenever events or changes in circumstances indicate that the carrying amount of our investments may not be recoverable. For the years ended December 31, 2022 and 2021, there were no indicators of impairment. (See Note 6. Equity Investments.)
Goodwill. The Company assesses the impairment of goodwill annually in the fourth quarter and whenever an event occurs or circumstances change that would indicate that the carrying amount may be impaired. The Company’s goodwill is a result of the New Energy acquisition in 2022. (See Note 1. Operations and Significant Accounting Policies and Note 5. Acquisitions.) The aggregate carrying amount of goodwill was $154.9 million as of December 31, 2022.
Property, Plant and Equipment. The Company assesses the impairment of property, plant, and equipment whenever events or changes in circumstances indicate that the carrying amount of property, plant, and equipment assets may not be recoverable. (See Note 1. Operations and Significant Accounting Policies.) For the years ended December 31, 2022, and 2021, there was no impairment of property, plant, and equipment.
We believe that long-standing ratemaking practices approved by applicable state and federal regulatory commissions allow for the recovery of the remaining book value of retired plant assets. The MPUC order for Minnesota Power’s 2015 IRP directed Minnesota Power to retire Boswell Units 1 and 2, which occurred in the fourth quarter of 2018. As part of the 2016 general retail rate case, the MPUC allowed recovery of the remaining book value of Boswell Units 1 and 2 through 2022. Minnesota Power’s latest IRP, which was approved by the MPUC in an order dated January 9, 2023, includes ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. Boswell Unit 3 and Unit 4 have a net book value of approximately $235 million and $435 million, respectively, as of December 31, 2022. (See Note 4. Regulatory Matters.) Minnesota Power’s latest IRP also includes the retirement of Taconite Harbor. As of December 31, 2022, Taconite Harbor had a net book value of approximately $25 million. We do not expect to record any impairment charge as a result of these operating changes at Taconite Harbor and Boswell. In addition, we expect to be able to continue depreciating these assets for at least their established remaining useful lives; however, we are unable to predict the impact of regulatory outcomes resulting in changes to their established remaining useful lives.
NOTE 8. SHORT-TERM AND LONG-TERM DEBT
Short-Term Debt. As of December 31, 2022, total short-term debt outstanding was $272.6 million ($214.2 million as of December 31, 2021), and consisted of long-term debt due within one year and included $0.1 million of unamortized debt issuance costs.
As of December 31, 2022, we had consolidated bank lines of credit aggregating $475.7 million ($432.0 million as of December 31, 2021), most of which expire in January 2026. We had $32.8 million outstanding in standby letters of credit and $31.3 million outstanding draws under our lines of credit as of December 31, 2022 ($31.5 million in standby letters of credit and $159.7 million outstanding draws as of December 31, 2021).
ALLETE, Inc. 2022 Form 10-K
97
NOTE 8. SHORT-TERM AND LONG-TERM DEBT (Continued)
Long-Term Debt. As of December 31, 2022, total long-term debt outstanding was $1,648.2 million ($1,763.2 million as of December 31, 2021) and included $8.2 million of unamortized debt issuance costs. The aggregate amount of long-term debt maturing in 2023 is $91.9 million; $94.8 million in 2024; $386.1 million in 2025; $79.4 million in 2026; $122.5 million in 2027; and $1,154.4 million thereafter. Substantially all of our regulated electric plant is subject to the lien of the mortgages collateralizing outstanding first mortgage bonds. The mortgages contain non-financial covenants customary in utility mortgages, including restrictions on our ability to incur liens, dispose of assets, and merge with other entities.
Minnesota Power is obligated to make financing payments for the Camp Ripley solar array totaling $1.4 million annually during the financing term, which expires in 2027. Minnesota Power has the option at the end of the financing term to renew for a two‑year term, or to purchase the solar array for approximately $4 million. Minnesota Power anticipates exercising the purchase option when the term expires.
On February 28, 2022, ALLETE entered into an unsecured term loan agreement (February Term Loan) to borrow up to $175 million. No draws were made on the February Term Loan, which was subsequently terminated in April 2022.
On March 24, 2022, ALLETE entered into a $170 million unsecured term loan agreement (March Term Loan). The Term Loan is due March 23, 2023, and may be repaid at any time. Interest is payable monthly at a rate per annum equal to SOFR plus 0.75 percent. Proceeds from the Term Loan were used for general corporate purposes.
On August 9, 2022, ALLETE issued $75 million of its First Mortgage Bonds (Bonds) to certain institutional buyers in the private placement market. The Bonds, which bear interest at 4.54 percent, will mature in August 2032 and pay interest semi-annually in February and August of each year, commencing on February 9, 2023. ALLETE has the option to prepay all or a portion of the Bonds at its discretion, subject to a make-whole provision. The Bonds are subject to additional terms and conditions which are customary for these types of transactions. Proceeds from the sale of the Bonds were used to refinance existing indebtedness and for general corporate purposes. The Bonds were sold in reliance on an exemption from registration under Section 4(a)(2) of the Securities Act of 1933, as amended, to institutional accredited investors.
ALLETE, Inc. 2022 Form 10-K
98
NOTE 8. SHORT-TERM AND LONG-TERM DEBT (Continued)
Long-Term Debt (Continued)
| | | | | | | | |
| Long-Term Debt | | |
| As of December 31 | 2022 | 2021 |
| Millions | | |
| First Mortgage Bonds | | |
| | |
| | |
| 3.40% Series Due 2022 | — | $75.0 |
| 6.02% Series Due 2023 | $75.0 | 75.0 |
| 3.69% Series Due 2024 | 60.0 | 60.0 |
| 4.90% Series Due 2025 | 30.0 | 30.0 |
| 5.10% Series Due 2025 | 30.0 | 30.0 |
| 3.20% Series Due 2026 | 75.0 | 75.0 |
| 5.99% Series Due 2027 | 60.0 | 60.0 |
| 3.30% Series Due 2028 | 40.0 | 40.0 |
| 4.08% Series Due 2029 | 70.0 | 70.0 |
| 3.74% Series Due 2029 | 50.0 | 50.0 |
| 2.50% Series Due 2030 | 46.0 | 46.0 |
| 3.86% Series Due 2030 | 60.0 | 60.0 |
| 2.79% Series Due 2031 | 100.0 | 100.0 |
| 4.54% Series Due 2032 | 75.0 | — |
| 5.69% Series Due 2036 | 50.0 | 50.0 |
| 6.00% Series Due 2040 | 35.0 | 35.0 |
| 5.82% Series Due 2040 | 45.0 | 45.0 |
| 4.08% Series Due 2042 | 85.0 | 85.0 |
| 4.21% Series Due 2043 | 60.0 | 60.0 |
| 4.95% Series Due 2044 | 40.0 | 40.0 |
| 5.05% Series Due 2044 | 40.0 | 40.0 |
| 4.39% Series Due 2044 | 50.0 | 50.0 |
| 4.07% Series Due 2048 | 60.0 | 60.0 |
| 4.47% Series Due 2049 | 30.0 | 30.0 |
| 3.30% Series Due 2050 | 94.0 | 94.0 |
| | |
| | |
| | |
| Armenia Mountain Senior Secured Notes 3.26% Due 2024 | 19.3 | 29.1 |
| Industrial Development Variable Rate Demand Refunding Revenue Bonds Series 2006, Due 2025 | 27.8 | 27.8 |
| Revolving Credit Facility Variable Rate Due 2026 | 13.0 | 145.0 |
| Senior Unsecured Notes 2.65% Due 2025 | 150.0 | 150.0 |
| Senior Unsecured Notes 3.11% Due 2027 | 80.0 | 80.0 |
| SWL&P First Mortgage Bonds 4.15% Series Due 2028 | 15.0 | 15.0 |
| SWL&P First Mortgage Bonds 4.14% Series Due 2048 | 12.0 | 12.0 |
| | |
| Unsecured Term Loan Variable Rate Due 2022 | — | 110.0 |
| Unsecured Term Loan Variable Rate Due 2023 | 170.0 | — |
| Other Long-Term Debt, 2022 Weighted Average Rate 4.94% Due 2024 – 2051 | 82.0 | 57.5 |
| Unamortized Debt Issuance Costs | (8.3) | (9.0) |
| Total Long-Term Debt | 1,920.8 | 1,977.4 |
| Less: Due Within One Year | 272.6 | 214.2 |
| Net Long-Term Debt | $1,648.2 | $1,763.2 |
ALLETE, Inc. 2022 Form 10-K
99
NOTE 8. SHORT-TERM AND LONG-TERM DEBT (Continued)
Long-Term Debt (Continued)
Financial Covenants. Our long-term debt arrangements contain customary covenants. In addition, our lines of credit and letters of credit supporting certain long-term debt arrangements contain financial covenants. Our compliance with financial covenants is not dependent on debt ratings. The most restrictive financial covenant requires ALLETE to maintain a ratio of indebtedness to total capitalization (as the amounts are calculated in accordance with the respective long-term debt arrangements) of less than or equal to 0.65 to 1.00, measured quarterly. As of December 31, 2022, our ratio was approximately 0.40 to 1.00. Failure to meet this covenant would give rise to an event of default if not cured after notice from the lender, in which event ALLETE may need to pursue alternative sources of funding. Some of ALLETE’s debt arrangements contain “cross-default” provisions that would result in an event of default if there is a failure under other financing arrangements to meet payment terms or to observe other covenants that would result in an acceleration of payments due. ALLETE has no significant restrictions on its ability to pay dividends from retained earnings or net income. As of December 31, 2022, ALLETE was in compliance with its financial covenants.
NOTE 9. COMMITMENTS, GUARANTEES AND CONTINGENCIES
The following table details the estimated minimum payments for certain long-term commitments as of December 31, 2022:
| | | | | | | | | | | | | | | | | | | | |
| 2023 | 2024 | 2025 | 2026 | 2027 | Thereafter |
| Millions | | | | | | |
| | | | | | |
| Capital Purchase Obligations | $26.6 | | $10.6 | | $1.3 | | $2.7 | | — | | $0.6 | |
Easements (a) | $7.8 | | $7.9 | | $8.0 | | $8.1 | | $8.2 | | $206.9 | |
PPAs (b) | $151.3 | | $145.8 | | $137.0 | | $136.9 | | $123.6 | | $1,010.3 | |
Other Purchase Obligations (c) | $49.9 | | $10.2 | | $6.5 | | — | | — | | — | |
(a)Easement obligations represent the minimum payments for our land easement agreements at our wind energy facilities.
(b)Does not include the Oliver Wind I, Oliver Wind II or Nobles 2 PPAs, as Minnesota Power only pays for energy as it is delivered. (See Power Purchase Agreements.)
(c)Consists of long-term service agreements for wind energy facilities and minimum purchase commitments under coal and rail contracts.
Power Purchase and Sales Agreements. Our long-term PPAs have been evaluated under the accounting guidance for variable interest entities. We have determined that either we have no variable interest in the PPAs, or where we do have variable interests, we are not the primary beneficiary; therefore, consolidation is not required. These conclusions are based on the fact that we do not have both control over activities that are most significant to the entity and an obligation to absorb losses or receive benefits from the entity’s performance. Our financial exposure relating to these PPAs is limited to our capacity and energy payments.
These agreements have also been evaluated under the accounting guidance for derivatives. We have determined that either these agreements are not derivatives, or, if they are derivatives, the agreements qualify for the normal purchases and normal sales exception to derivative accounting guidance; therefore, derivative accounting is not required.
Square Butte PPA. Minnesota Power has a PPA with Square Butte that extends through 2026 (Agreement). Minnesota Power is obligated to pay its pro rata share of Square Butte’s costs based on its entitlement to the output of Square Butte’s 455 MW coal‑fired generating unit. Minnesota Power’s output entitlement under the Agreement is 50 percent for the remainder of the Agreement, subject to the provisions of the Minnkota Power PSA described in the following table. Minnesota Power’s payment obligation will be suspended if Square Butte fails to deliver any power, whether produced or purchased, for a period of one year. Square Butte’s costs consist primarily of debt service, operating and maintenance, depreciation and fuel expenses. As of December 31, 2022, Square Butte had total debt outstanding of $210.2 million. Annual debt service for Square Butte is expected to be approximately $47.2 million in 2023, $32.2 million in 2024, $28.4 million in 2025, and $28.6 million in 2026 of which Minnesota Power’s obligation is 50 percent. Fuel expenses are recoverable through Minnesota Power’s fuel adjustment clause and include the cost of coal purchased from BNI Energy under a long-term contract.
ALLETE, Inc. 2022 Form 10-K
100
NOTE 9. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Power Purchase and Sales Agreements (Continued)
Minnesota Power’s cost of power purchased from Square Butte during 2022 was $82.7 million ($82.4 million in 2021; $79.5 million in 2020). This reflects Minnesota Power’s pro rata share of total Square Butte costs based on the 50 percent output entitlement. Included in this amount was Minnesota Power’s pro rata share of interest expense of $5.1 million in 2022 ($5.8 million in 2021; $7.1 million in 2020). Minnesota Power’s payments to Square Butte are approved as a purchased power expense for ratemaking purposes by both the MPUC and the FERC.
Minnesota Power has also entered into the following long-term PPAs for the purchase of capacity and energy as of December 31, 2022:
| | | | | | | | | | | | | | | | | |
| Counterparty | Quantity | Product | Commencement | Expiration | Pricing |
| PPAs | | | | | |
| Calpine Corporation | 25 MW | Capacity | June 2019 | May 2026 | Fixed |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| Manitoba Hydro | | | | | |
| | | | | |
| | | | | |
| PPA 1 | 250 MW | Capacity / Energy | June 2020 | May 2035 | (a) |
| PPA 2 | 133 MW | Energy | June 2020 | June 2040 | Forward Market Prices |
| | | | | |
| Nobles 2 | 250 MW | Capacity / Energy | December 2020 | December 2040 | Fixed |
| Oliver Wind I | (b) | Energy | December 2006 | December 2040 | Fixed |
| Oliver Wind II | (b) | Energy | December 2007 | December 2040 | Fixed |
| | | | | |
| | | | | |
(a)The capacity price was adjusted annually until 2020 by the change in a governmental inflationary index. The energy price is based on a formula that includes an annual fixed component adjusted for the change in a governmental inflationary index and a natural gas index, as well as market prices.
(b)The PPAs provide for the purchase of all output from the 50 MW Oliver Wind I and 48 MW Oliver Wind II wind energy facilities.
Minnesota Power has also entered into the following long-term PSAs for the sale of capacity and energy as of December 31, 2022:
| | | | | | | | | | | | | | | | | |
| Counterparty | Quantity | Product | Commencement | Expiration | Pricing |
| PSAs | | | | | |
| Basin | | | | | |
| | | | | |
| | | | | |
| PSA 1 | (a) | Capacity | June 2022 | May 2025 | Fixed |
| PSA 2 | 100 MW | Capacity | June 2025 | May 2028 | Fixed |
| Great River Energy | 100 MW | Capacity | June 2022 | May 2025 | Fixed |
| Minnkota Power | (b) | Capacity / Energy | June 2014 | December 2026 | (b) |
| Oconto Electric Cooperative | 25 MW | Capacity / Energy | January 2019 | May 2026 | Fixed |
| Silver Bay Power | (c) | Energy | January 2017 | December 2031 | (d) |
(a)The agreement provides for 75 MW of capacity from June 1, 2022, through May 31, 2023, and increases to 125 MW of capacity from June 1, 2023, through May 31, 2025.
(b)Minnesota Power is selling a portion of its entitlement from Square Butte to Minnkota Power, resulting in Minnkota Power’s net entitlement increasing and Minnesota Power’s net entitlement decreasing until Minnesota Power’s share is eliminated at the end of 2025. Of Minnesota Power’s 50 percent output entitlement, it sold to Minnkota Power approximately 32 percent in 2022 (28 percent in 2021 and in 2020). (See Square Butte PPA.)
(c)Silver Bay Power supplies approximately 90 MW of load to Northshore Mining, an affiliate of Silver Bay Power.
(d)The energy pricing escalates at a fixed rate annually and is adjusted for changes in a natural gas index.
ALLETE, Inc. 2022 Form 10-K
101
NOTE 9. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Coal, Rail and Shipping Contracts. Minnesota Power has coal supply agreements providing for the purchase of a significant portion of its coal requirements through December 2023. Minnesota Power also has coal transportation agreements in place for the delivery of a significant portion of its coal requirements through December 2024. The costs of fuel and related transportation costs for Minnesota Power’s generation are recoverable from Minnesota Power’s utility customers through the fuel adjustment clause.
Environmental Matters.
Our businesses are subject to regulation of environmental matters by various federal, state and local authorities. A number of regulatory changes to the Clean Air Act, the Clean Water Act and various waste management requirements have been promulgated by both the EPA and state authorities over the past several years. Minnesota Power’s facilities are subject to additional requirements under many of these regulations. Minnesota Power is reshaping its generation portfolio, over time, to reduce its reliance on coal, has installed cost-effective emission control technology, and advocates for sound science and policy during rulemaking implementation.
We consider our businesses to be in substantial compliance with currently applicable environmental regulations and believe all necessary permits have been obtained. We anticipate that with many state and federal environmental regulations and requirements finalized, or to be finalized in the near future, potential expenditures for future environmental matters may be material and require significant capital investments. Minnesota Power has evaluated various environmental compliance scenarios using possible outcomes of environmental regulations to project power supply trends and impacts on customers.
We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated based on current law and existing technologies. Accruals are adjusted as assessment and remediation efforts progress, or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the Consolidated Balance Sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are expensed unless recoverable in rates from customers.
Air. The electric utility industry is regulated both at the federal and state level to address air emissions. Minnesota Power’s thermal generating facilities mainly burn low-sulfur western sub-bituminous coal. All of Minnesota Power’s coal-fired generating facilities are equipped with pollution control equipment such as scrubbers, baghouses and low NOX technologies. Under currently applicable environmental regulations, these facilities are substantially compliant with emission requirements.
Cross-State Air Pollution Rule (CSAPR). The CSAPR requires certain states in the eastern half of the U.S., including Minnesota, to reduce power plant emissions that contribute to ozone or fine particulate pollution in other states. The CSAPR does not require installation of controls but does require facilities have sufficient allowances to cover their emissions on an annual basis. These allowances are allocated to facilities from each state’s annual budget, and can be bought and sold. Based on our review of the NOX and SO2 allowances issued and pending issuance, we currently expect generation levels and emission rates will result in continued compliance with the CSAPR. The EPA’s CSAPR Update Rule issued in March 2021 revising the 2016 CSAPR Update does not apply to the state of Minnesota and is therefore not currently projected to affect Minnesota Power’s CSAPR compliance. Minnesota Power will continue to monitor ongoing CSAPR rulemakings and compliance implementation, including the EPA’s Good Neighbor Rule proposed on April 6, 2022, to modify certain aspects of the CSAPR’s program scope and extent.
National Ambient Air Quality Standards (NAAQS). The EPA is required to review the NAAQS every five years. If the EPA determines that a state’s air quality is not in compliance with the NAAQS, the state is required to adopt plans describing how it will reduce emissions to attain the NAAQS. Minnesota Power actively monitors NAAQS developments and compliance costs for existing standards or proposed NAAQS revisions are not currently expected to be material. The EPA is currently reviewing the secondary NAAQS for NOx and SO2, as well as particulate matter. In June 2021, the EPA announced it will reconsider the December 2020 final rule retaining the 2012 particulate matter NAAQS. On January 6, 2023 the EPA announced a proposed rule to revise the primary annual particulate matter NAAQS from its current level while retaining the other primary and secondary particulate matter NAAQS. A final rule is expected by the end of 2023. The EPA also announced in October 2021 that it was reconsidering the 2020 Ozone NAAQS rule finalized in December 2020, and issued a policy assessment on April 28, 2022, recommending retention of the current standard. A proposed Ozone NAAQS rule is expected in the first half of 2023. Anticipated compliance costs related to the proposed and expected NAAQS revisions cannot yet be estimated; however, costs could be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.
ALLETE, Inc. 2022 Form 10-K
102
NOTE 9. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
EPA Good Neighbor Plan for 2015 Ozone NAAQS. On April 6, 2022, the EPA published a proposed rule, the Good Neighbor Plan, to address regional ozone transport for the 2015 Ozone NAAQS by reducing NOx emissions during the period of May 1 through September 30 (ozone season). This rule is intended to address certain good neighbor or interstate transport provisions of the Clean Air Act relative to the 2015 Ozone NAAQS. In the justification for the proposed rule, the EPA asserted that 26 states, including Minnesota, are modeled as significant contributors to downwind states’ challenges in attaining or maintaining ozone NAAQS compliance within their state borders. The Good Neighbor Plan proposes to resolve this interstate transport issue by implementing a variety of NOx reduction strategies, including federal implementation plan requirements, NOx emission limitations, and ozone season allowance program requirements, beginning with the 2023 ozone season. The proposed rule would apply to fossil-fuel fired power plants in 25 states and certain other industrial sources in 23 states. Implementation of the rule would occur in part through changes to the existing CSAPR program.
Minnesota Power reviewed the proposed rule, assessed its potential impacts and submitted public comments to the EPA on June 21, 2022. Concerns noted by Minnesota Power and other entities included the technical accuracy of the EPA’s assumptions and methods used to identify Minnesota as a significant contributor state, as well as the proposed rule’s intended timeline. Anticipated compliance costs related to the Good Neighbor Plan cannot yet be estimated; however, the costs could be material, including costs of additional NOx controls, emission allowance program participation, or operational changes, if any are required. Minnesota Power would seek recovery of additional costs through a rate proceeding. The EPA intends to issue a final rule in early 2023, following a final action to approve or disapprove the ozone transport State Implementation Plans (SIPs). On January 31, 2023, the EPA announced its final action to partially disapprove SIPs for the states of Minnesota and Wisconsin, and to disapprove 19 other SIP submissions. The Company is currently reviewing this SIP final action and any associated costs cannot yet be anticipated until the issuance of the EPA’s final Good Neighbor Plan, which is expected in March 2023.
EPA National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial and Institutional Boilers and Process Heaters (Industrial Boiler MACT) Rule. A final rule issued by the EPA for Industrial Boiler MACT became effective in 2013 with compliance required at major existing sources in 2016. Minnesota Power’s Hibbard Renewable Energy Center and Rapids Energy Center are subject to this rule. Compliance with the Industrial Boiler MACT Rule consisted largely of adjustments to fuels and operating practices and compliance costs were not material. Subsequent to this initial rulemaking, litigation from 2016 through 2018 resulted in court orders directing that the EPA reconsider certain aspects of the regulation including the basis for and numerical value of several different emission limits. On October 6, 2022, the EPA published a final rule in the Federal Register incorporating these changes. The rule became effective on December 5, 2022, imposing a 3-year compliance deadline of October 6, 2025. Minnesota Power’s initial review of this new rule indicates that the revisions should not significantly impact the Company’s affected units. As such, compliance costs associated with the new Industrial Boiler MACT Rule are not currently expected to be material; however Minnesota Power would seek recovery of additional costs through a rate proceeding.
Climate Change. The scientific community generally accepts that emissions of GHGs are linked to global climate change which creates physical and financial risks. Physical risks could include, but are not limited to: increased or decreased precipitation and water levels in lakes and rivers; increased or other changes in temperatures; increased risk of wildfires; and changes in the intensity and frequency of extreme weather events. These all have the potential to affect the Company’s business and operations. We are addressing climate change by taking the following steps that also ensure reliable and environmentally compliant generation resources to meet our customers’ requirements:
•Expanding renewable power supply for both our operations and the operations of others;
•Providing energy conservation initiatives for our customers and engaging in other demand side management efforts;
•Improving efficiency of our generating facilities;
•Supporting research of technologies to reduce carbon emissions from generating facilities and carbon sequestration efforts;
•Evaluating and developing less carbon intensive future generating assets such as efficient and flexible natural gas‑fired generating facilities;
•Managing vegetation on right-of-way corridors to reduce potential wildfire or storm damage risks; and
•Practicing sound forestry management in our service territories to create landscapes more resilient to disruption from climate-related changes, including planting and managing long-lived conifer species.
ALLETE, Inc. 2022 Form 10-K
103
NOTE 9. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
EPA Regulation of GHG Emissions. In 2019, the EPA finalized several separate rulemakings regarding regulating carbon emissions from electric utility generating units. These rulemakings included repealing the Clean Power Plan (CPP) and adopting the Affordable Clean Energy Rule under Section 111(d) of the Clean Air Act (CAA) to regulate CO2 emissions at existing coal-fired power plants. The CPP was first announced as a proposed rule under Section 111(d) of the CAA for existing power plants entitled “Carbon Pollution Emission Guidelines for Existing Stationary Sources: Electric Generating Units”. The Affordable Clean Energy Rule established emissions guidelines for states to use when developing plans to limit CO2 from coal-fired power plants. The EPA also published regulations for the state implementation of the Affordable Clean Energy Rule and other Section 111(d) rules. Affected facilities for Minnesota Power included Boswell Units 3 and 4, Hibbard Units 3 and 4, and Taconite Harbor Units 1 and 2; Taconite Harbor Units 1 and 2 are currently economically idled.
In January 2021, the D.C. Circuit issued an opinion vacating the Affordable Clean Energy Rule and remanded the Affordable Clean Energy Rule back to the EPA for further consideration, consistent with the D.C. Circuit’s finding that the EPA erred in interpreting the CAA, pending rehearing or appeal. Four petitions for review of the D.C. Circuit’s opinion were subsequently granted by the U.S. Supreme Court in October 2021, consolidated under West Virginia v. EPA et al. On June 30, 2022, the U.S. Supreme Court released its opinion in favor of West Virginia and aligned parties. The Supreme Court found the EPA’s CPP structure of generation shifting to be disallowed under Section 111(d) of the CCA on grounds of the major questions doctrine. The court did not opine upon the regulatory approach the EPA proposed in the Affordable Clean Energy Rule. The petitions were remanded to the D.C. Circuit. The EPA has indicated that it intends to issue a proposed rule in early 2023 with a new set of emission guidelines for states to follow in submitting state plans to establish and implement standards of performance for GHG emissions from existing fossil fuel-fired electric generating units. Minnesota Power will continue to monitor any related guidelines and rulemakings issued by the EPA or state regulatory authorities.
In April 2021, the Biden Administration announced a goal to reach 100 percent carbon pollution-free electricity by 2035 as part of the Nationally Determined Contributions pledge, which is part of an international effort to limit global warming. At this time, no specific regulatory pathway to achieve these reductions has been proposed. Minnesota Power will continue to monitor these developments.
Minnesota had already initiated several measures consistent with those called for under the now repealed CPP and vacated Affordable Clean Energy Rule. Minnesota Power continues implementing its EnergyForward strategic plan that provides for significant emission reductions and diversifying its electricity generation mix to include more renewable and natural gas energy. We are unable to predict the GHG emission compliance costs we might incur as a result of a replacement for the Affordable Clean Energy Rule or other future laws, regulations or administrative policies; however, the costs could be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.
Minnesota had already initiated several measures consistent with those called for under the now repealed CPP and vacated Affordable Clean Energy Rule. Minnesota Power continues implementing its EnergyForward strategic plan that provides for significant emission reductions and diversifying its electricity generation mix to include more renewable and natural gas energy. We are unable to predict the GHG emission compliance costs we might incur as a result of a replacement for the Affordable Clean Energy Rule or other future laws, regulations or administrative policies; however, the costs could be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.
Additionally in January 2021, the EPA issued a rulemaking to apply CO2 emission New Source Performance Standards (NSPS) to new, modified and reconstructed fossil fuel-fired electric generating units under Section 111(b) of the CAA. Currently, the EPA is a performing a comprehensive review of the Section 111(b) GHG NSPS for electric generating units, with a notice of proposed rulemaking expected in early 2023. Minnesota Power is monitoring the NSPS final rule and any further Section 111(b) developments including their potential impact to the Company. The proposed combined-cycle natural gas-fired generating facility, NTEC, is expected to meet these NSPS requirements.
ALLETE, Inc. 2022 Form 10-K
104
NOTE 9. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
Water. The Clean Water Act requires NPDES permits be obtained from the EPA (or, when delegated, from individual state pollution control agencies) for any wastewater discharged into navigable waters. We have obtained all necessary NPDES permits, including NPDES storm water permits for applicable facilities, to conduct our operations.
Steam Electric Power Generating Effluent Limitations Guidelines. In 2015, the EPA issued revised federal effluent limitation guidelines (ELG) for steam electric power generating stations under the Clean Water Act. It set effluent limits and prescribed BACT for several wastewater streams, including flue gas desulphurization (FGD) water, bottom ash transport water and coal combustion landfill leachate. In 2017, the EPA announced a two-year postponement of the ELG compliance date of November 1, 2018, to November 1, 2020, while the agency reconsidered the bottom ash transport water (BATW) and FGD wastewater provisions. On April 12, 2019, the U.S. Court of Appeals for the Fifth Circuit vacated and remanded back to the EPA portions of the ELG that allowed for continued discharge of legacy wastewater and leachate. On October 13, 2020, the EPA published a final ELG Rule allowing re-use of bottom ash transport water in FGD scrubber systems with limited discharges related to maintaining system water balance. The rule sets technology standards and numerical pollutant limits for discharges of bottom ash transport water and FGD wastewater. Compliance deadlines depend on subcategory, with compliance generally required as soon as possible, beginning after October 13, 2021, but no later than December 31, 2025, or December 31, 2028, in some specific cases. The rule also established new subcategories for retiring high-flow and low-utilization units, and established a voluntary incentives program for FGD wastewater. In accordance with the January 2021 Executive Order 13990, the EPA was mandated to conduct a review of actions and polices taken during the prior administration, including the 2020 ELG Rule. On September 14, 2021, the EPA published a notice of availability for its preliminary effluent guidelines program plan. In the plan, the EPA confirmed the agency is initiating a rulemaking process to strengthen wastewater pollution limitations from FGD and bottom ash transport water discharges while the 2020 ELG Rule remains in effect. The EPA is expected to publish a proposed rule in 2023.
Under the 2020 ELG rule, most bottom ash transport water discharge to surface waters must cease no later than December 31, 2025, except for small discharges needed to retain water balance. The majority of bottom ash transport will either need to be re-used in a closed-loop process or routed to a FGD scrubber. FGD wastewater is required to meet stringent water quality standards for discharge to surface water.
Bottom ash transport and FGD wastewater ELG’s are not currently expected to have a significant impact on Minnesota Power operations. Boswell Energy Center, where ELG’s are primarily applicable, completed conversion to dry bottom ash handling and installed a FGD dewatering system in September 2022. The dry conversion projects eliminated bottom ash transport water and minimized wastewater from the FGD system. Re-use and onsite consumption is planned for the remaining FGD waste stream and for dewatering legacy wastewater from Boswell’s existing impoundments. Water re-use and consumption activities are expected to eliminate the need for surface water discharges prior to the current ELG Rule deadline of December 31, 2025.
The EPA’s additional reconsideration of legacy wastewater and leachate discharge requirements has the potential to impact leachate discharges associated with the closed impoundment at the Laskin and Taconite Harbor Energy Centers Dry Ash Landfill. In its spring 2022 Unified Agenda, the EPA announced it intends to consolidate consideration of legacy wastewater and leachate with the ELG/FGD and BATW proposed rulemaking currently expected in 2023. It is unknown at this time if the rule revisions will include new requirements for these waste streams.
At this time, we estimate no additional material compliance costs for ELG bottom ash water and FGD requirements. Compliance costs we might incur related to other ELG waste streams (e.g., leachate) or other potential future water discharge regulations at Minnesota Power facilities cannot be estimated; however, the costs could be material, including costs associated with wastewater treatment and re-use. Minnesota Power would seek recovery of additional costs through a rate proceeding.
ALLETE, Inc. 2022 Form 10-K
105
NOTE 9. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
Permitted Water Discharges – Sulfate. In 2017, the MPCA released a draft water quality standard in an attempt to update Minnesota’s existing 10 mg/L sulfate limit for waters used for the production of wild rice with the proposed rulemaking heard before an administrative law judge (ALJ). In 2018, the ALJ rejected significant portions of the proposed rulemaking and the MPCA subsequently withdrew the rulemaking. The existing 10 mg/L limit remains in place, but the MPCA is currently prohibited under state law from listing wild rice waters as impaired or requiring sulfate reduction technology.
In April 2021, the MPCA’s proposed list of impaired waters submitted pursuant to the Clean Water Act was partially rejected by the EPA due to the absence of wild rice waters listed for sulfate impairment. The EPA transmitted a final list of 32 EPA-added wild rice waters to the MPCA in November 2021. This list could subsequently be used to set sulfate limits in discharge permits for power generation facilities and municipal and industrial customers, including paper and pulp facilities, and mining operations. At this time we are unable to determine the specific impacts these developments may have on Minnesota Power operations, if any. Minnesota Power would seek recovery of additional costs through a rate proceeding.
Solid and Hazardous Waste. The Resource Conservation and Recovery Act of 1976 regulates the management and disposal of solid and hazardous wastes. We are required to notify the EPA of hazardous waste activity and, consequently, routinely submit reports to the EPA.
Coal Ash Management Facilities. Minnesota Power produces the majority of its coal ash at Boswell, with small amounts of ash generated at Hibbard Renewable Energy Center. Ash storage and disposal methods include storing ash in clay-lined onsite impoundments (ash ponds), disposing of dry ash in a lined dry ash landfill, applying ash to land as an approved beneficial use, and trucking ash to state permitted landfills.
Coal Combustion Residuals from Electric Utilities (CCR). In 2015, the EPA published the final rule (2015 Rule) regulating CCR as nonhazardous waste under Subtitle D of the Resource Conservation and Recovery Act (RCRA) in the Federal Register. The rule includes additional requirements for new landfill and impoundment construction as well as closure activities related to certain existing impoundments. Costs of compliance for Boswell and Laskin are expected to be incurred primarily over the next 15 years and be between approximately $65 million and $120 million. Compliance costs for CCR at Taconite Harbor are not expected to be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.
Minnesota Power continues to work on minimizing costs through evaluation of beneficial re-use and recycling of CCR and CCR-related waters. In 2017, the EPA announced its intention to formally reconsider the CCR rule under Subtitle D of the RCRA. In March 2018, the EPA published the first phase of the proposed rule revisions in the Federal Register. In 2018, the EPA finalized revisions to elements of the CCR rule, including extending certain deadlines by two years, the establishment of alternative groundwater protection standards for certain constituents and the potential for risk-based management options at facilities based on site characteristics. In 2018, a U.S. District Court for the District of Columbia decision vacated specific provisions of the CCR rule. The court decision resulted in a change to the status of three existing clay-lined impoundments at Boswell that must now be considered unlined. The EPA proposed additional rule revisions in 2019 to address outstanding issues from litigation and closure timelines for unlined impoundments, respectively. The first of these rules, CCR Part A Rule, was finalized in September 2020. The Part A Rule revision requires unlined impoundments to cease disposal of waste as soon as technically feasible but no later than April 11, 2021. Minnesota Power sought EPA approval under the Part A Rule to extend the closure date for two active Boswell impoundments in November 2020. Upon completion of dry ash conversion activities, Boswell ceased disposal in both impoundments on September 17, 2022 and formally withdrew the CCR Part A Application. The EPA acknowledged the Part A variance application withdrawal on September 20, 2022, and indicated that no further EPA review of Boswell’s Part A variance application will occur. Both impoundments are now inactive and have initiated closure.
Additionally, the EPA released a proposed Part B rulemaking in February 2020 addressing options for beneficial reuse of CCR materials, alternative liner demonstrations, and other CCR regulatory revisions. Portions of the Part B Rule addressing alternative liner equivalency standards were finalized in November 2020. According to the EPA’s updated fall 2022 regulatory agenda, finalization of the remainder of the proposed Part B Rule is expected in late 2023. Two additional rulemakings are also expected in mid-2023, the proposed Legacy Impoundment Rule and the Final Federal Permit Rule. The Legacy Impoundment Rule will include a revised definition for legacy CCR Impoundments which could regulate impoundments that had closed prior to the effective date of the 2015 Rule. The Final Federal Permit Rule will finalize procedures for implementing a CCR Federal Permit Program. Expected compliance costs at Boswell due to the 2018 court decision and subsequent rule revisions are reflected in our estimate of compliance costs for the CCR rule noted previously.
ALLETE, Inc. 2022 Form 10-K
106
NOTE 9. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
Other Environmental Matters
Manufactured Gas Plant Site. We are reviewing and addressing environmental conditions at a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. SWL&P has been working with the Wisconsin Department of Natural Resources (WDNR) in determining the extent and location of contamination at the site and surrounding properties. As of December 31, 2022, we have recorded a liability of $14.9 million for remediation costs at this site. SWL&P has recorded the site as an associated regulatory asset as we expect recovery of these remediation costs to be allowed by the PSCW. The majority of remediation costs are expected to be incurred through 2023.
Other Matters
We have multiple credit facility agreements in place that provide the ability to issue standby letters of credit to satisfy our contractual security requirements across our businesses. As of December 31, 2022, we had $290.3 million of outstanding letters of credit issued, including those issued under our revolving credit facility.
Regulated Operations. As of December 31, 2022, we had $28.2 million outstanding in standby letters of credit at our Regulated Operations which are pledged as security for MISO and state agency agreements as well as energy facilities under development.
ALLETE Clean Energy. ALLETE Clean Energy is party to PSAs that expire in various years between 2024 and 2039. As of December 31, 2022, ALLETE Clean Energy has $222.3 million outstanding in standby letters of credit, the majority of which are pledged as security under these PSAs and PSAs for wind energy facilities under development.
Corporate and Other.
BNI Energy. As of December 31, 2022, BNI Energy had surety bonds outstanding of $82.4 million related to the reclamation liability for closing costs associated with its mine and mine facilities. Although its coal supply agreements obligate the customers to provide for the closing costs, additional assurance is required by federal and state regulations. BNI Energy’s total reclamation liability is currently estimated at $82.1 million. BNI Energy does not believe it is likely that any of these outstanding surety bonds will be drawn upon.
Investment in Nobles 2. Nobles 2 wind energy facility requires standby letters of credit as security for certain contractual obligations. As of December 31, 2022, ALLETE South Wind has $11.7 million outstanding in standby letters of credit, related to our portion of the security requirements relative to our ownership in Nobles 2.
New Energy. As of December 31, 2022, New Energy had $4.2 million outstanding in standby letters of credit pledged as security in connection with the acquisition of solar equipment for projects under development. New Energy does not believe it is likely that any of these outstanding letters of credit will be drawn upon.
South Shore Energy. As of December 31, 2022, South Shore Energy had $23.9 million outstanding in standby letters of credit pledged as security in connection with the development of NTEC. South Shore Energy does not believe it is likely that any of these outstanding letters of credit will be drawn upon.
ALLETE Properties. As of December 31, 2022, ALLETE Properties had surety bonds outstanding and letters of credit to governmental entities totaling $2.0 million primarily related to development and maintenance obligations for various projects. The estimated cost of the remaining development work is $1.0 million. ALLETE Properties does not believe it is likely that any of these outstanding surety bonds or letters of credit will be drawn upon.
ALLETE, Inc. 2022 Form 10-K
107
NOTE 9. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Other Matters (Continued
Community Development District Obligations. In 2005, the Town Center District issued $26.4 million of tax-exempt, 6.0 percent capital improvement revenue bonds. The capital improvement revenue bonds are payable over 31 years (by May 1, 2036) and are secured by special assessments on the benefited land. To the extent that ALLETE Properties still owns land at the time of the assessment, it will incur the cost of its portion of these assessments, based upon its ownership of benefited property.
As of December 31, 2022, we owned 42 percent of the assessable land in the Town Center District (30 percent as of December 31, 2021). As of December 31, 2022, ownership levels, our annual assessments related to capital improvement and special assessment bonds for the ALLETE Properties project within the district is approximately $1.3 million. As we sell property at this project, the obligation to pay special assessments will pass to the new landowners. In accordance with accounting guidance, these bonds are not reflected as debt on our Consolidated Balance Sheet.
Legal Proceedings.
We are involved in litigation arising in the normal course of business. Also in the normal course of business, we are involved in tax, regulatory and other governmental audits, inspections, investigations and other proceedings that involve state and federal taxes, safety, and compliance with regulations, rate base and cost of service issues, among other things. We do not expect the outcome of these matters to have a material effect on our financial position, results of operations or cash flows.
NOTE 10. COMMON STOCK AND EARNINGS PER SHARE
| | | | | | | | |
| Summary of Common Stock | Shares | Equity |
| | Thousands | Millions |
| Balance as of December 31, 2019 | 51,679 | | $1,436.7 | |
| Employee Stock Purchase Plan | 13 | | 0.7 | |
| Invest Direct | 309 | | 18.3 | |
| Share-Based Compensation | 84 | | 5.2 | |
| | |
| | |
| | |
| | |
| | |
| | |
| Balance as of December 31, 2020 | 52,085 | | 1,460.9 | |
| Employee Stock Purchase Plan | 17 | | 0.8 | |
| Invest Direct | 263 | | 17.5 | |
| Share-Based Compensation | 73 | | 6.5 | |
| | |
| Equity Issuance Program | 782 | | 51.0 | |
| | |
| | |
| | |
| | |
| Balance as of December 31, 2021 | 53,220 | | 1,536.7 | |
| Employee Stock Purchase Plan | 11 | | 0.9 | |
| Invest Direct | 244 | | 14.9 | |
| Share-Based Compensation | 82 | | 5.3 | |
| | |
| Equity Issuance | 3,680 | | 223.7 | |
| | |
| | |
| | |
| Balance as of December 31, 2022 | 57,237 | | $1,781.5 | |
Equity Issuance Program. We entered into a distribution agreement with Lampert Capital Markets, in 2008, as amended most recently in 2020, with respect to the issuance and sale of up to an aggregate of 13.6 million shares of our common stock, without par value, of which 2.1 million shares remain available for issuance as of December 31, 2022. For the year ended December 31, 2022, no shares of common stock were issued under this agreement (0.8 million shares for net proceeds of $51.0 million in 2021; none in 2020) .
On April 5, 2022, ALLETE issued and sold approximately 3.7 million shares of ALLETE common stock. Net proceeds of approximately $224 million were received from the sale of shares. Proceeds were used primarily to fund the acquisition of New Energy and capital investments at ALLETE Clean Energy.
ALLETE, Inc. 2022 Form 10-K
108
NOTE 10. COMMON STOCK AND EARNINGS PER SHARE (Continued)
Earnings Per Share. We compute basic earnings per share using the weighted average number of shares of common stock outstanding during each period. The difference between basic and diluted earnings per share, if any, arises from non-vested restricted stock units and performance share awards granted under our Executive Long-Term Incentive Compensation Plan.
| | | | | | | | | | | |
| Reconciliation of Basic and Diluted | | | |
| Earnings Per Share | | Dilutive | |
| Year Ended December 31 | Basic | Securities | Diluted |
| Millions Except Per Share Amounts | | | |
| 2022 | | | |
| Net Income Attributable to ALLETE | $189.3 | | | $189.3 | |
| Average Common Shares | 55.9 | | 0.1 | | 56.0 | |
| Earnings Per Share | $3.38 | | | $3.38 | |
| | | |
| 2021 | | | |
| Net Income Attributable to ALLETE | $169.2 | | | $169.2 | |
| Average Common Shares | 52.4 | | 0.1 | | 52.5 | |
| Earnings Per Share | $3.23 | | | $3.23 | |
| | | |
| 2020 | | | |
| Net Income Attributable to ALLETE | $165.4 | | | $165.4 | |
| Average Common Shares | 51.9 | | — | | 51.9 | |
| Earnings Per Share | $3.18 | | | $3.18 | |
| | | |
NOTE 11. INCOME TAX EXPENSE
| | | | | | | | | | | |
| Income Tax Expense | | | |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Millions | | | |
Current Income Tax Expense (a) | | | |
| Federal | $1.2 | | — | | — | |
| State | 6.1 | | — | | — | |
| Total Current Income Tax Expense | $7.3 | | — | | — | |
| Deferred Income Tax Expense (Benefit) | | | |
Federal (b) | $(32.8) | $(37.2) | $(51.5) |
| | | |
State (c) | (5.2) | | 10.8 | | 8.6 | |
| | | |
| Investment Tax Credit Amortization | (0.5) | (0.5) | (0.5) |
| Total Deferred Income Tax Expense (Benefit) | $(38.5) | $(26.9) | $(43.4) |
| Total Income Tax Expense (Benefit) | $(31.2) | $(26.9) | $(43.4) |
(a)For the years ended December 31, 2021 and 2020, the federal and state current tax expense was minimal due to NOLs which resulted from the bonus depreciation provisions of certain tax legislation. Federal and state NOLs are being carried forward to offset current and future taxable income. For the year ended December 31, 2022, federal NOLs were fully utilized and production tax credits were used to partially offset federal taxable income.
(b)For the years ended December 31, 2022, 2021 and 2020, the federal tax benefit is primarily due to production tax credits.
(c)For the year ended December 31, 2022, the state impact includes the benefit of deferred repricing as a result of the New Energy acquisition.
ALLETE, Inc. 2022 Form 10-K
109
NOTE 11. INCOME TAX EXPENSE (Continued)
| | | | | | | | | | | | | | |
| Reconciliation of Taxes from Federal Statutory | | | | |
| Rate to Total Income Tax Expense | | | | |
| Year Ended December 31 | 2022 | 2021 | 2020 | |
| Millions | | | | |
| Income Before Non-Controlling Interest and Income Taxes | $100.1 | | $110.9 | | $109.4 | | |
| Statutory Federal Income Tax Rate | 21 | % | 21 | % | 21 | % | |
| Income Taxes Computed at Statutory Federal Rate | $21.0 | | $23.3 | | $23.0 | | |
| Increase (Decrease) in Tax Due to: | | | | |
| State Income Taxes | 8.6 | | 8.6 | | 6.5 | | |
| Deferred Income Tax Revaluation | (7.9) | | — | | — | | |
| | | | |
| | | | |
| Production Tax Credits | (50.7) | | (53.5) | | (62.7) | | |
| Investment Tax Credits | (4.1) | | — | | — | | |
Regulatory Differences – Excess Deferred Tax Benefit (a) | (9.1) | | (9.5) | | (9.9) | | |
| | | | |
| | | | |
| Non-Controlling Interest | 11.2 | | 6.3 | | 2.7 | | |
| AFUDC - Equity | (1.1) | | (1.0) | | (0.8) | | |
| Other | 0.9 | | (1.1) | | (2.2) | | |
| Total Income Tax Benefit | $(31.2) | $(26.9) | $(43.4) | |
(a)Excess deferred income taxes are being returned to customers under both the Average Rate Assumption Method and amortization periods as approved by regulators. (See Note 4. Regulatory Matters.)
The effective tax rate was a benefit of 31.2 percent for 2022 (benefit of 24.3 percent for 2021; benefit of 39.7 percent for 2020). The 2022 and 2021 effective tax rates were primarily impacted by production tax credits and non-controlling interests in subsidiaries. The 2020 effective tax rate was primarily impacted by production tax credits.
| | | | | | | | |
| Deferred Income Tax Assets and Liabilities | | |
| As of December 31 | 2022 | 2021 |
| Millions | | |
| Deferred Income Tax Assets | | |
| Employee Benefits and Compensation | $46.4 | | $44.5 | |
| Property-Related | 61.9 | | 54.8 | |
| NOL Carryforwards | 16.7 | | 67.5 | |
| Capital Loss Carryforwards | 13.1 | | — | |
| Tax Credit Carryforwards | 548.7 | | 509.1 | |
| Power Sales Agreements | 13.7 | | 16.5 | |
| Regulatory Liabilities | 95.5 | | 101.5 | |
| Other | 28.1 | | 18.0 | |
| Gross Deferred Income Tax Assets | 824.1 | | 811.9 | |
| Deferred Income Tax Asset Valuation Allowance | (60.2) | | (69.0) | |
| Total Deferred Income Tax Assets | $763.9 | | $742.9 | |
| Deferred Income Tax Liabilities | | |
| Deferred Gain | $7.9 | | $7.9 | |
| Property-Related | 661.7 | | 680.8 | |
| Regulatory Asset for Benefit Obligations | 57.7 | | 54.9 | |
| Unamortized Investment Tax Credits | 30.0 | | 30.5 | |
| Partnership Basis Differences | 126.0 | | 106.3 | |
| Fuel Adjustment Clause | 10.7 | | 14.3 | |
| Regulatory Assets | 28.0 | | 30.0 | |
| Total Deferred Income Tax Liabilities | $922.0 | | $924.7 | |
Net Deferred Income Taxes (a) | $158.1 | | $181.8 | |
| | |
| | |
| | |
| | |
| | |
(a)Recorded as a net Deferred Income Tax liability on the Consolidated Balance Sheet.
ALLETE, Inc. 2022 Form 10-K
110
NOTE 11. INCOME TAX EXPENSE (Continued)
| | | | | | | | |
| NOL and Tax Credit Carryforwards | | |
| As of December 31 | 2022 | 2021 |
| Millions | | |
Federal NOL Carryforwards (a) | — | | $177.3 | |
| Federal Tax Credit Carryforwards | $464.5 | $416.4 |
Federal Capital Loss (a) | $35.1 | — | |
State NOL Carryforwards (a) | $323.0 | $506.9 |
State Tax Credit Carryforwards (b) | $24.5 | $24.2 |
State Capital Loss (a) | $83.2 | — | |
(a)Pre-tax amounts.
(b)Net of a $59.6 million valuation allowance as of December 31, 2022 ($68.6 million as of December 31, 2021).
The federal NOL, capital loss and tax credit carryforward periods expire between 2026 and 2043. We expect to fully utilize the federal NOL, capital loss and tax credit carryforwards; therefore, no federal valuation allowance has been recognized as of December 31, 2022. The pre-apportioned state NOL, capital loss and tax credit carryforward periods expire between 2023 and 2046. We have established a valuation allowance against certain state NOL, capital loss and tax credits that we do not expect to utilize before their expiration.
| | | | | | | | | | | |
| Gross Unrecognized Income Tax Benefits | 2022 | 2021 | 2020 |
| Millions | | | |
| Balance at January 1 | $1.3 | | $1.4 | | $1.4 | |
| Additions for Tax Positions Related to the Current Year | — | | — | | 0.1 | |
| | | |
| Reductions for Tax Positions Related to Prior Years | — | | (0.1) | | (0.1) | |
| | | |
| | | |
| Balance as of December 31 | $1.3 | | $1.3 | | $1.4 | |
Unrecognized tax benefits are the differences between a tax position taken or expected to be taken in a tax return and the benefit recognized and measured pursuant to the “more-likely-than-not” criteria. The unrecognized tax benefit balance includes permanent tax positions which, if recognized would affect the annual effective income tax rate. In addition, the unrecognized tax benefit balance includes temporary tax positions for which the ultimate deductibility is highly certain but for which there is uncertainty about the timing of such deductibility. A change in the period of deductibility would not affect the effective tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. The gross unrecognized tax benefits as of December 31, 2022, included $0.6 million of net unrecognized tax benefits which, if recognized, would affect the annual effective income tax rate.
As of December 31, 2022, we had immaterial accrued interest (none as of December 31, 2021, and 2020) related to unrecognized tax benefits included on the Consolidated Balance Sheet due to our NOL carryforwards. We classify interest related to unrecognized tax benefits as interest expense and tax-related penalties in operating expenses on the Consolidated Statement of Income. Interest expense related to unrecognized tax benefits on the Consolidated Statement of Income was immaterial in 2022, 2021 and 2020. There were no penalties recognized in 2022, 2021 or 2020. The unrecognized tax benefit amounts have been presented as an increase to the net deferred tax liability on the Consolidated Balance Sheet.
No material changes to unrecognized tax benefits are expected during the next 12 months.
ALLETE and its subsidiaries file a consolidated federal income tax return as well as combined and separate state income tax returns in various jurisdictions. ALLETE is currently under examination by the state of Wisconsin for the tax years 2018 through 2020. ALLETE has no open federal audits, and is no longer subject to federal examination for years before 2019 or state examination for years before 2018. Additionally, the statute of limitations related to the federal tax credit carryforwards will remain open until those credits are utilized in subsequent returns.
ALLETE, Inc. 2022 Form 10-K
111
NOTE 12. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS
We have noncontributory union, non-union and combined retiree defined benefit pension plans covering eligible employees. The combined retiree defined benefit pension plan was created in 2016, to include all union and non-union retirees from the existing plans as of January 2016. The plans provide defined benefits based on years of service and final average pay. We made no contributions to the plan trusts in 2022 ($10.3 million in 2021; $10.7 million in 2020). We also have a defined contribution RSOP covering substantially all employees. The 2022 plan year employer contributions totaled $12.0 million ($11.5 million for the 2021 plan year; $11.2 million for the 2020 plan year). (See Note 10. Common Stock and Earnings Per Share and Note 13. Employee Stock and Incentive Plans.)
The non-union defined benefit pension plan was frozen in 2018, and does not allow further crediting of service or earnings to the plan. Further, it is closed to new participants. The Minnesota Power union defined benefit pension plan is also closed to new participants, and the SWL&P union defined benefit pension plan was closed to new participants effective February 1, 2022.
We have postretirement health care and life insurance plans covering eligible employees. In 2010, the postretirement health care plan was closed to employees hired after January 2011, and the eligibility requirements were amended. In 2014, the postretirement life plan was amended to close the plan to non-union employees retiring after December 2015, and in 2018, the postretirement life plan was amended to limit the benefit level for union employees retiring after December 2018. The postretirement health and life plans are contributory with participant contributions adjusted annually. Postretirement health and life benefits are funded through a combination of Voluntary Employee Benefit Association trusts (VEBAs), established under section 501(c)(9) of the Internal Revenue Code, and irrevocable grantor trusts. In 2022, no contributions were made to the VEBAs (none in 2021; none in 2020) and no contributions were made to the grantor trusts (none in 2021; none in 2020).
Management considers various factors when making funding decisions such as regulatory requirements, actuarially determined minimum contribution requirements and contributions required to avoid benefit restrictions for the pension plans. Contributions are based on estimates and assumptions which are subject to change. On January 17, 2023, we contributed $6.5 million in cash to the defined benefit pension plans. We do not expect to make any further contributions to the defined benefit pension plans in 2023, and we do not expect to make any contributions to the defined benefit postretirement health and life plans in 2023.
Accounting for defined benefit pension and other postretirement benefit plans requires that employers recognize on a prospective basis the funded status of their defined benefit pension and other postretirement plans on their balance sheet and recognize as a component of other comprehensive income, net of tax, the gains or losses and prior service costs or credits that arise during the period but are not recognized as components of net periodic benefit cost.
The defined benefit pension and postretirement health and life benefit expense (credit) recognized annually by our regulated utilities are expected to be recovered (refunded) through rates filed with our regulatory jurisdictions. As a result, these amounts that are required to otherwise be recognized in accumulated other comprehensive income have been recognized as a long-term regulatory asset (regulatory liability) on the Consolidated Balance Sheet, in accordance with the accounting standards for the effect of certain types of regulation applicable to our Regulated Operations. The defined benefit pension and postretirement health and life benefit expense (credits) associated with our other operations are recognized in accumulated other comprehensive income.
ALLETE, Inc. 2022 Form 10-K
112
NOTE 12. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)
| | | | | | | | |
| Pension Obligation and Funded Status |
| As of December 31 | 2022 | 2021 |
| Millions | | |
| Accumulated Benefit Obligation | $724.5 | | $875.5 | |
| Change in Benefit Obligation | | |
| Obligation, Beginning of Year | $911.7 | | $965.7 | |
| Service Cost | 9.3 | | 11.0 | |
| Interest Cost | 27.2 | | 24.6 | |
| Plan Amendments | 0.8 | | — | |
| Plan Curtailments | — | | (1.4) | |
Actuarial Gain (a) | (160.6) | | (39.0) | |
| Benefits Paid | (58.9) | | (56.5) | |
| Participant Contributions | 10.2 | | 7.3 | |
| Obligation, End of Year | $739.7 | | $911.7 | |
| Change in Plan Assets | | |
| Fair Value, Beginning of Year | $745.7 | | $759.4 | |
| Actual Return on Plan Assets | (130.5) | | 23.1 | |
Employer Contribution (b) | 12.3 | | 19.7 | |
| Benefits Paid | (58.9) | | (56.5) | |
| Fair Value, End of Year | $568.6 | | $745.7 | |
| Funded Status, End of Year | $(171.1) | $(166.0) |
| | |
| Net Pension Amounts Recognized in Consolidated Balance Sheet Consist of: | | |
| Current Liabilities | $(2.1) | $(2.1) |
Non-Current Liabilities (c) | $(169.0) | $(163.9) |
(a) Actuarial gain was primarily the result of increases in discount rates in 2022 and 2021.
(b) Includes Participant Contributions noted above, any contributions made by the Company to pension plan trusts and any direct benefit payments made under certain plans.
(c) Presented here net of amounts related to prepaid pension for SWL&P that are reclassified to Regulatory Assets on the Consolidated Balance Sheet.
The pension costs that are reported as a component within the Consolidated Balance Sheet, reflected in long-term regulatory assets or liabilities and accumulated other comprehensive income, consist of a net loss of $260.2 million and prior service credit of $0.1 million as of December 31, 2022 (net loss of $260.2 million and prior service credit of $1.0 million as of December 31, 2021).
ALLETE, Inc. 2022 Form 10-K
113
NOTE 12. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)
| | | | | | | | |
| Reconciliation of Net Pension Amounts Recognized in Consolidated Balance Sheet |
| As of December 31 | 2022 | 2021 |
| Millions | | |
| Net Loss | $(260.2) | $(260.2) |
| Prior Service Credit | 0.1 | 1.0 |
| Accumulated Contributions in Excess of Net Periodic Benefit Cost (Prepaid Pension Asset) | 89.0 | 93.2 |
| Total Net Pension Amounts Recognized in Consolidated Balance Sheet | $(171.1) | $(166.0) |
| | | | | | | | | | | |
| Components of Net Periodic Pension Cost |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Millions | | | |
| Service Cost | $9.3 | | $11.0 | | $10.7 | |
Non-Service Cost Components (a) | | | |
| Interest Cost | 27.2 | | 24.6 | | 27.9 | |
| Expected Return on Plan Assets | (41.5) | | (43.4) | | (42.7) | |
| Amortization of Loss | 11.4 | | 18.8 | | 12.8 | |
| Amortization of Prior Service Credit | (0.1) | | (0.2) | | (0.2) | |
| Net Pension Cost | $6.3 | | $10.8 | | $8.5 | |
(a)These components of net periodic pension cost are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.
| | | | | | | | |
Other Changes in Pension Plan Assets and Benefit Obligations Recognized in
Other Comprehensive Income and Regulatory Assets or Liabilities |
| Year Ended December 31 | 2022 | 2021 |
| Millions | | |
| Net (Gain) Loss | $11.4 | $(20.1) |
| Amortization of Prior Service Credit | 0.1 | | 0.2 | |
| Prior Service Credit Arising During the Period | 0.8 | | — | |
| Amortization of Loss | (11.4) | | (18.8) | |
| Total Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities | $0.9 | $(38.7) |
| | | | | | | | |
| Information for Pension Plans with an Accumulated Benefit Obligation in Excess of Plan Assets |
| As of December 31 | 2022 | 2021 |
| Millions | | |
| Projected Benefit Obligation | $739.7 | | $911.7 | |
| Accumulated Benefit Obligation | $724.5 | | $875.5 | |
| Fair Value of Plan Assets | $568.6 | | $745.7 | |
ALLETE, Inc. 2022 Form 10-K
114
NOTE 12. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)
| | | | | | | | |
| Postretirement Health and Life Obligation and Funded Status |
| As of December 31 | 2022 | 2021 |
| Millions | | |
| Change in Benefit Obligation | | |
| Obligation, Beginning of Year | $148.2 | | $167.6 | |
| Service Cost | 3.0 | | 3.6 | |
| Interest Cost | 4.4 | | 4.4 | |
Actuarial Gain (a) | (38.7) | | (19.7) | |
| Benefits Paid | (9.2) | | (10.6) | |
| Participant Contributions | 2.7 | | 2.9 | |
| | |
| | |
| | |
| Obligation, End of Year | $110.4 | | $148.2 | |
| Change in Plan Assets | | |
| Fair Value, Beginning of Year | $201.8 | | $186.0 | |
| Actual Return on Plan Assets | (33.0) | | 22.8 | |
| Employer Contribution | 0.3 | | 0.7 | |
| Participant Contributions | 2.7 | | 2.9 | |
| Benefits Paid | (9.2) | | (10.6) | |
| Fair Value, End of Year | $162.6 | $201.8 |
| Funded Status, End of Year | $52.2 | $53.6 |
| | |
| Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet Consist of: | | |
| Non-Current Assets | $58.8 | $64.8 |
| Current Liabilities | $(0.2) | $(1.4) |
| Non-Current Liabilities | $(6.4) | $(9.8) |
(a)Actuarial gain was primarily the result of increases in discount rates in 2022 and 2021.
According to the accounting standards for retirement benefits, only assets in the VEBAs are treated as plan assets in the preceding table for the purpose of determining funded status. In addition to the postretirement health and life assets reported in the previous table, we had $11.8 million in irrevocable grantor trusts included in Other Non-Current Assets on the Consolidated Balance Sheet as of December 31, 2022 ($13.2 million as of December 31, 2021).
The postretirement health and life costs that are reported as a component within the Consolidated Balance Sheet, reflected in regulatory long-term assets or liabilities and accumulated other comprehensive income, consist of the following:
| | | | | | | | |
| Unrecognized Postretirement Health and Life Costs |
| As of December 31 | 2022 | 2021 |
| Millions | | |
| Net Gain | $(9.2) | $(12.7) |
| Prior Service Credit | (13.2) | (20.7) |
| | |
| Total Unrecognized Postretirement Health and Life Cost | $(22.4) | $(33.4) |
ALLETE, Inc. 2022 Form 10-K
115
NOTE 12. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)
| | | | | | | | |
| Reconciliation of Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet |
| As of December 31 | 2022 | 2021 |
| Millions | | |
Net Gain (a) | $9.2 | $12.7 |
| Prior Service Credit | 13.2 | 20.7 |
Accumulated Net Periodic Benefit Cost in Excess of Contributions (a) | 29.8 | 20.2 |
| Total Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet | $52.2 | $53.6 |
(a)Excludes gains, losses and contributions associated with irrevocable grantor trusts.
| | | | | | | | | | | |
| Components of Net Periodic Postretirement Health and Life Cost |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Millions | | | |
| Service Cost | $3.0 | | $3.6 | | $3.3 | |
Non-Service Cost Components (a) | | | |
| Interest Cost | 4.4 | | 4.4 | | 5.0 | |
| Expected Return on Plan Assets | (9.6) | | (9.9) | | (9.7) | |
| Amortization of Loss | 0.4 | | 3.0 | | 1.0 | |
| Amortization of Prior Service Credit | (7.5) | | (7.6) | | (8.0) | |
| | | |
| Effect of Plan Curtailment | — | | — | | (0.3) | |
| Net Postretirement Health and Life Credit | $(9.3) | $(6.5) | $(8.7) |
(a)These components of net periodic postretirement health and life cost are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.
| | | | | | | | |
Other Changes in Postretirement Benefit Plan Assets and Benefit Obligations
Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities |
| Year Ended December 31 | 2022 | 2021 |
| Millions | | |
| Net (Gain) Loss | $3.9 | $(32.7) |
| | |
| Amortization of Prior Service Credit | 7.5 | | 7.6 | |
| | |
| Amortization of Loss | (0.4) | | (3.0) | |
| | |
| Total Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities | $11.0 | $(28.1) |
| | | | | | | | |
| Estimated Future Benefit Payments | Pension | Postretirement Health and Life |
| Millions | | |
| 2023 | $58.0 | $7.2 | |
| 2024 | $58.4 | $7.5 | |
| 2025 | $58.0 | $7.5 | |
| 2026 | $57.3 | $7.7 | |
| 2027 | $57.0 | $8.0 | |
| Years 2028 – 2032 | $274.9 | $42.4 | |
ALLETE, Inc. 2022 Form 10-K
116
NOTE 12. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)
| | | | | | | | |
| Weighted Average Assumptions Used to Determine Benefit Obligation |
| As of December 31 | 2022 | 2021 |
| Discount Rate | | |
| Pension | 5.70% | 3.05% |
| Postretirement Health and Life | 5.68% | 3.09% |
| Rate of Compensation Increase | 3.58% | 3.58% |
| Health Care Trend Rates | | |
| Trend Rate | 6.50% | 5.66% |
| Ultimate Trend Rate | 5.00% | 4.50% |
| Year Ultimate Trend Rate Effective | 2038 | 2038 |
| | | | | | | | | | | |
| Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Discount Rate | | | |
| Pension | 3.28% | 2.87% | 3.52% |
| Postretirement Health and Life | 3.09% | 2.70% | 3.45% |
| Expected Long-Term Return on Plan Assets | | | |
| Pension | 6.00% | 6.50% | 6.75% |
| Postretirement Health and Life | 5.41% | 5.85% | 6.08% |
| Rate of Compensation Increase | 3.58% | 3.62% | 4.06% |
In establishing the expected long-term rate of return on plan assets, we determine the long-term historical performance of each asset class, adjust these for current economic conditions, and utilizing the target allocation of our plan assets, forecast the expected long-term rate of return.
The discount rate is computed using a bond matching study which utilizes a portfolio of high quality bonds that produce cash flows similar to the projected costs of our pension and other postretirement plans.
The Company utilizes actuarial assumptions about mortality to calculate the pension and postretirement health and life benefit obligations. The mortality assumptions used to calculate our pension and other postretirement benefit obligations as of December 31, 2022, considered a modified PRI-2012 mortality table and MP-2021 mortality projection scale.
ALLETE, Inc. 2022 Form 10-K
117
NOTE 12. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)
| | | | | | | | | | | | | | |
| Actual Plan Asset Allocations | Pension | Postretirement Health and Life (a) |
| | 2022 | 2021 | 2022 | 2021 |
| Equity Securities | 46% | 49% | 66% | 70% |
| Fixed Income Securities | 50% | 48% | 34% | 29% |
| Private Equity | — | — | — | 1% |
| Real Estate | 4% | 3% | — | — |
| | 100% | 100% | 100% | 100% |
(a)Includes VEBAs and irrevocable grantor trusts.
There were no shares of ALLETE common stock included in pension plan equity securities as of December 31, 2022 (no shares as of December 31, 2021).
The defined benefit pension plans have adopted a dynamic asset allocation strategy (glide path) that increases the invested allocation to fixed income assets as the funding level of the plan increases to better match the sensitivity of the plan’s assets and liabilities to changes in interest rates. This is expected to reduce the volatility of reported pension plan expenses. The postretirement health and life plans’ assets are diversified to achieve strong returns within managed risk. Equity securities are diversified among domestic companies with large, mid and small market capitalizations, as well as investments in international companies. The majority of debt securities are made up of investment grade bonds.
Following are the current targeted allocations as of December 31, 2022:
| | | | | | | | |
| Plan Asset Target Allocations | Pension | Postretirement Health and Life (a) |
| Equity Securities | 49 | % | 65 | % |
| Fixed Income Securities | 50 | % | 35 | % |
| | |
| Real Estate | 1 | % | — | |
| | 100 | % | 100 | % |
(a)Includes VEBAs and irrevocable grantor trusts.
Fair Value
Fair value is 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 (exit price). We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. We primarily apply the market approach for recurring fair value measurements and endeavor to utilize the best available information. Accordingly, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. These inputs, which are used to measure fair value, are prioritized through the fair value hierarchy. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). (See Note 7. Fair Value.)
ALLETE, Inc. 2022 Form 10-K
118
NOTE 12. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)
Fair Value (Continued)
Pension Fair Value
| | | | | | | | | | | | | | |
| | Fair Value as of December 31, 2022 |
| Recurring Fair Value Measures | Level 1 | Level 2 | Level 3 | Total |
| Millions | | | | |
| Assets: | | | | |
| Equity Securities: | | | | |
U.S. Large-cap (a) | — | $61.2 | — | $61.2 |
U.S. Mid-cap Growth (a) | — | 40.0 | — | 40.0 |
U.S. Small-cap (a) | — | 35.4 | — | 35.4 |
| | | | |
| International | $127.0 | — | — | 127.0 |
| | | | |
| | | | |
| | | | |
Fixed Income Securities (a) | — | 275.3 | — | 275.3 |
| Cash and Cash Equivalents | 7.3 | — | — | 7.3 |
| | | | |
| | | | |
| Real Estate | — | — | $22.4 | 22.4 |
| Total Fair Value of Assets | $134.3 | $411.9 | $22.4 | $568.6 |
(a)The underlying investments consist of actively-managed funds managed to achieve the returns of certain U.S. equity and fixed income securities indexes.
| | | | | | |
| Recurring Fair Value Measures | | |
| Activity in Level 3 | | Real Estate |
| Millions | | |
| Balance as of December 31, 2021 | | $21.6 | |
| Actual Return on Plan Assets | | 1.0 | |
| Purchases, Sales, and Settlements – Net | | (0.2) | |
| Balance as of December 31, 2022 | | $22.4 |
| | | | | | | | | | | | | | |
| | Fair Value as of December 31, 2021 |
| Recurring Fair Value Measures | Level 1 | Level 2 | Level 3 | Total |
| Millions | | | | |
| Assets: | | | | |
| Equity Securities: | | | | |
U.S. Large-cap (a) | — | | $113.8 | | — | | $113.8 | |
U.S. Mid-cap Growth (a) | — | | 47.6 | | — | | 47.6 | |
U.S. Small-cap (a) | — | | 46.2 | | — | | 46.2 | |
| | | | |
| International | — | | 158.2 | | — | | 158.2 | |
| | | | |
| | | | |
| | | | |
Fixed Income Securities (a) | — | | 346.1 | | — | | 346.1 | |
| Cash and Cash Equivalents | $12.2 | | — | | — | | 12.2 | |
| | | | |
| | | | |
| Real Estate | — | | — | | $21.6 | | 21.6 | |
| Total Fair Value of Assets | $12.2 | | $711.9 | | $21.6 | | $745.7 | |
(a)The underlying investments consist of actively-managed funds managed to achieve the returns of certain U.S. equity and fixed income securities indexes.
ALLETE, Inc. 2022 Form 10-K
119
NOTE 12. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)
Fair Value (Continued)
| | | | | | | | | | | |
| Recurring Fair Value Measures | | | |
| Activity in Level 3 | | Private Equity Funds | Real Estate |
| Millions | | | |
| Balance as of December 31, 2020 | | $7.0 | | $18.0 | |
| Actual Return on Plan Assets | | (3.5) | | 3.6 | |
| Purchases, Sales, and Settlements – Net | | (3.5) | | — | |
| Balance as of December 31, 2021 | | — | | $21.6 | |
Postretirement Health and Life Fair Value
| | | | | | | | | | | | | | |
| | Fair Value as of December 31, 2022 |
| Recurring Fair Value Measures | Level 1 | Level 2 | Level 3 | Total |
| Millions | | | | |
| Assets: | | | | |
Equity Securities: (a) | | | | |
| U.S. Large-cap | $26.7 | | — | | — | | $26.7 | |
| U.S. Mid-cap Growth | 25.5 | | — | | — | | 25.5 | |
| U.S. Small-cap | 12.7 | | — | | — | | 12.7 | |
| International | 41.5 | | — | | — | | 41.5 | |
| Fixed Income Securities: | | | | |
| Mutual Funds | 55.5 | | — | | — | | 55.5 | |
| | | | |
| Cash and Cash Equivalents | 0.7 | | — | | — | | 0.7 | |
| | | | |
| | | | |
| Total Fair Value of Assets | $162.6 | | — | | — | | $162.6 | |
(a)The underlying investments consist of mutual funds (Level 1).
| | | | | |
| Recurring Fair Value Measures | |
| Activity in Level 3 | Private Equity Funds |
| Millions | |
| Balance as of December 31, 2021 | $2.0 | |
| Actual Return on Plan Assets | (1.5) | |
| Purchases, Sales, and Settlements – Net | (0.5) | |
| Balance as of December 31, 2022 | — | |
ALLETE, Inc. 2022 Form 10-K
120
NOTE 12. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)
Fair Value (Continued)
| | | | | | | | | | | | | | |
| | Fair Value as of December 31, 2021 |
| Recurring Fair Value Measures | Level 1 | Level 2 | Level 3 | Total |
| Millions | | | | |
| Assets: | | | | |
Equity Securities: (a) | | | | |
| U.S. Large-cap | $40.1 | | — | | — | | $40.1 | |
| U.S. Mid-cap Growth | 37.3 | | — | | — | | 37.3 | |
| U.S. Small-cap | 19.3 | | — | | — | | 19.3 | |
| International | 43.7 | | — | | — | | 43.7 | |
| Fixed Income Securities: | | | | |
| Mutual Funds | 56.7 | | — | | — | | 56.7 | |
| Debt Securities | — | | $1.8 | | — | | 1.8 | |
| Cash and Cash Equivalents | 0.9 | | — | | — | | 0.9 | |
| | | | |
| Private Equity Funds | — | | — | | $2.0 | | 2.0 | |
| Total Fair Value of Assets | $198.0 | | $1.8 | | $2.0 | | $201.8 | |
(a)The underlying investments consist of mutual funds (Level 1).
| | | | | |
| Recurring Fair Value Measures | |
| Activity in Level 3 | Private Equity Funds |
| Millions | |
| Balance as of December 31, 2020 | $1.7 | |
| Actual Return on Plan Assets | 0.8 | |
| Purchases, Sales, and Settlements – Net | (0.5) | |
| Balance as of December 31, 2021 | $2.0 | |
Accounting and disclosure requirements for the Medicare Prescription Drug, Improvement and Modernization Act of 2003 (Act) provide guidance for employers that sponsor postretirement health care plans that provide prescription drug benefits. We provide a fully insured postretirement health benefit, including a prescription drug benefit, which qualifies us for a federal subsidy under the Act. The federal subsidy is reflected in the premiums charged to us by the insurance company.
NOTE 13. EMPLOYEE STOCK AND INCENTIVE PLANS
Employee Stock Ownership Plan. We sponsor an ESOP within the RSOP. Eligible employees may contribute to the RSOP plan as of their date of hire. The dividends received by the ESOP are distributed to participants. Dividends on allocated ESOP shares are recorded as a reduction of retained earnings. ESOP employer allocations are funded with contributions paid in either cash or the issuance of ALLETE common stock at the Company’s discretion. We record compensation expense equal to the cash or current market price of stock contributed. ESOP compensation expense was $12.0 million in 2022 ($11.5 million in 2021; $11.2 million in 2020).
According to the accounting standards for stock compensation, unallocated shares of ALLETE common stock held and purchased by the ESOP were treated as unearned ESOP shares and not considered outstanding for earnings per share computations. All ESOP shares have been allocated to participants as of December 31, 2022, 2021 and 2020.
Stock-Based Compensation.
Stock Incentive Plan. Under our Executive Long-Term Incentive Compensation Plan (Executive Plan), share-based awards may be issued to key employees through a broad range of methods, including non-qualified and incentive stock options, performance shares, performance units, restricted stock, restricted stock units, stock appreciation rights and other awards. There are 0.8 million shares of ALLETE common stock reserved for issuance under the Executive Plan, of which 0.6 million of these shares remain available for issuance as of December 31, 2022.
ALLETE, Inc. 2022 Form 10-K
121
NOTE 13. EMPLOYEE STOCK AND INCENTIVE PLANS (Continued)
Stock-Based Compensation (Continued)
The following types of share-based awards were outstanding in 2022, 2021 or 2020:
Performance Shares. Under the performance share awards, the number of shares earned is contingent upon attaining specific market and performance goals over a three-year performance period. Market goals are measured by total shareholder return relative to a group of peer companies while performance goals are measured by earnings per share growth. In the case of qualified retirement, death, or disability during a performance period, a pro rata portion of the award will be earned at the conclusion of the performance period based on the market goals achieved. In the case of termination of employment for any reason other than qualified retirement, death, or disability, no award will be earned. If there is a change in control, a pro rata portion of the award will be paid based on the greater of actual performance up to the date of the change in control or target performance. The fair value of these awards incorporates the probability of meeting the total shareholder return goals. Compensation cost is recognized over the three-year performance period based on our estimate of the number of shares which will be earned by the award recipients.
Restricted Stock Units. Under the restricted stock unit awards, shares for participants eligible for retirement vest monthly over a three-year period. For participants not eligible for retirement, shares vest at the end of the three-year period. In the case of qualified retirement, death or disability, a pro rata portion of the award will be earned. In the case of termination of employment for any reason other than qualified retirement, death or disability, no award will be earned. If there is a change in control, a pro rata portion of the award will be earned. The fair value of these awards is equal to the grant date fair value. Compensation cost is recognized over the three-year vesting period based on our estimate of the number of shares which will be earned by the award recipients.
Employee Stock Purchase Plan (ESPP). Under our ESPP, eligible employees may purchase ALLETE common stock at a 5 percent discount from the market price; we are not required to apply fair value accounting to these awards as the discount is not greater than 5 percent.
RSOP. The RSOP is a contributory defined contribution plan subject to the provisions of the Employee Retirement Income Security Act of 1974, as amended, and qualifies as an employee stock ownership plan and profit sharing plan. The RSOP provides eligible employees an opportunity to save for retirement.
The following share-based compensation expense amounts were recognized in our Consolidated Statement of Income for the periods presented.
| | | | | | | | | | | |
| Share-Based Compensation Expense |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Millions | | | |
| | | |
| Performance Shares | $0.7 | | $2.0 | | $2.2 | |
| Restricted Stock Units | 0.9 | | 1.0 | | 0.9 | |
| Total Share-Based Compensation Expense | $1.6 | | $3.0 | | $3.1 | |
| Income Tax Benefit | $0.5 | | $0.9 | | $0.9 | |
There were no capitalized share-based compensation costs during the years ended December 31, 2022, 2021 or 2020.
As of December 31, 2022, the total unrecognized compensation cost for the performance share awards and restricted stock units not yet recognized in our Consolidated Statement of Income was $1.9 million and $0.8 million, respectively. These amounts are expected to be recognized over a weighted-average period of 1.7 years and 1.6 years, respectively.
ALLETE, Inc. 2022 Form 10-K
122
NOTE 13. EMPLOYEE STOCK AND INCENTIVE PLANS (Continued)
Stock-Based Compensation (Continued)
Performance Shares. The following table presents information regarding our non-vested performance shares.
| | | | | | | | | | | | | | | | | | | | |
| | 2022 | 2021 | 2020 |
| Number of
Shares | Weighted-
Average
Grant Date
Fair Value | Number of
Shares | Weighted-
Average
Grant Date
Fair Value | Number of
Shares | Weighted-
Average
Grant Date
Fair Value |
| Non-vested as of January 1 | 80,661 | | $75.80 | | 85,284 | | $80.73 | | 99,585 | | $72.78 | |
Granted (a) | 37,731 | | $67.22 | | 33,304 | | $73.25 | | 25,763 | | $83.17 | |
| Awarded | — | | — | | — | | — | | (25,304) | | $62.03 | |
| Unearned Grant Award | (50,524) | | $77.49 | | (33,375) | | $86.09 | | (13,625) | | $62.03 | |
| Forfeited | (7,379) | | $71.00 | | (4,552) | | $74.05 | | (1,135) | | $79.81 | |
| Non-vested as of December 31 | 60,489 | | $69.62 | | 80,661 | | $75.80 | | 85,284 | | $80.73 | |
(a) Shares granted include accrued dividends.
There were approximately 51,000 performance shares granted in February 2023 for the three-year performance period ending in 2025. The ultimate issuance is contingent upon the attainment of certain goals of ALLETE during the performance periods. The grant date fair value of the performance shares granted was $3.4 million. There were no performance shares awarded in February 2023.
Restricted Stock Units. The following table presents information regarding our available restricted stock units.
| | | | | | | | | | | | | | | | | | | | |
| | 2022 | 2021 | 2020 |
| Number of
Shares | Weighted- Average
Grant Date
Fair Value | Number of
Shares | Weighted- Average
Grant Date
Fair Value | Number of
Shares | Weighted- Average
Grant Date
Fair Value |
| Available as of January 1 | 28,141 | | $73.16 | | 37,482 | | $77.64 | | 39,943 | | $69.30 | |
Granted (a) | 15,477 | | $63.70 | | 16,251 | | $64.97 | | 15,169 | | $83.48 | |
| Awarded | (7,396) | | $75.55 | | (23,631) | | $74.53 | | (17,193) | | $63.41 | |
| Forfeited | (2,658) | | $66.44 | | (1,961) | | $74.52 | | (437) | | $77.52 | |
| Available as of December 31 | 33,564 | | $68.80 | | 28,141 | | $73.16 | | 37,482 | | $77.64 | |
(a) Shares granted include accrued dividends.
There were approximately 14,700 restricted stock units granted in February 2023 for the vesting period ending in 2025. The grant date fair value of the restricted stock units granted was $0.9 million. There were approximately 8,500 restricted stock units awarded in February 2023. The grant date fair value of the shares awarded was $0.7 million.
NOTE 14. BUSINESS SEGMENTS
We present two reportable segments: Regulated Operations and ALLETE Clean Energy. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment.
Regulated Operations includes three operating segments which consist of our regulated utilities, Minnesota Power and SWL&P, as well as our investment in ATC. ALLETE Clean Energy is our business focused on developing, acquiring and operating clean and renewable energy projects. We also present Corporate and Other which includes three operating segments, New Energy, a renewable energy development company, BNI Energy, our coal mining operations in North Dakota, and ALLETE Properties, our legacy Florida real estate investment, along with our investment in Nobles 2, South Shore Energy, our non-rate regulated, Wisconsin subsidiary developing NTEC, other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, land holdings in Minnesota, and earnings on cash and investments.
ALLETE, Inc. 2022 Form 10-K
123
NOTE 14. BUSINESS SEGMENTS (Continued)
| | | | | | | | | | | |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Millions | | | |
| Operating Revenue | | | |
| Residential | $175.9 | | $160.8 | | $140.7 | |
| Commercial | 187.2 | | 168.6 | | 139.5 | |
| Municipal | 40.2 | | 52.0 | | 41.2 | |
| Industrial | 589.0 | | 565.5 | | 432.8 | |
| Other Power Suppliers | 165.8 | | 168.7 | | 138.8 | |
| | | |
| Other | 101.2 | | 112.3 | | 94.3 | |
| Total Regulated Operations | 1,259.3 | | 1,227.9 | | 987.3 | |
| | | |
| | | |
| | | |
| ALLETE Clean Energy | | | |
| Long-term PSA | 77.2 | | 75.5 | | 68.3 | |
| Sale of Wind Energy Facility | 33.5 | | — | | — | |
| Other | 7.6 | | 11.4 | | 11.3 | |
| Total ALLETE Clean Energy | 118.3 | | 86.9 | | 79.6 | |
| | | |
| Corporate and Other | | | |
| Long-term Contract | 89.2 | | 84.4 | | 86.0 | |
| Sale of Renewable Development Projects | 73.9 | | — | | — | |
| Other | 30.0 | | 20.0 | | 16.2 | |
| Total Corporate and Other | 193.1 | | 104.4 | | 102.2 | |
| Total Operating Revenue | $1,570.7 | | $1,419.2 | | $1,169.1 | |
Net Income Attributable to ALLETE (a) | | | |
| Regulated Operations | $149.9 | | $129.1 | | $136.3 | |
| | | |
| | | |
| ALLETE Clean Energy | 16.3 | | 26.3 | | 21.1 | |
| | | |
| | | |
Corporate and Other (b)(c) | 23.1 | | 13.8 | | 8.0 | |
| Total Net Income Attributable to ALLETE | $189.3 | | $169.2 | | $165.4 | |
(a) Includes interest expense resulting from intercompany loan agreements and allocated to certain subsidiaries. The amounts are eliminated in consolidation.
(b) Net Income in 2022 includes a $8.3 million after-tax expense as a result of purchase price accounting related to projects under development at the time of acquisition and $2.7 million after-tax of transaction costs related to the acquisition of New Energy.
(c) In 2021, South Shore Energy sold a portion of its undivided ownership interest in NTEC to Basin. The closing of the transaction resulted in the recognition of an approximately $8.5 million after-tax gain which is reflected in Corporate and Other. (See Note 1. Operations and Significant Accounting Policies.)
ALLETE, Inc. 2022 Form 10-K
124
NOTE 14. BUSINESS SEGMENTS (Continued)
| | | | | | | | | | | |
| Year Ended December 31 | 2022 | 2021 | 2020 |
| Millions | | | |
| Depreciation and Amortization | | | |
| Regulated Operations | $171.9 | | $170.7 | | $166.9 | |
| | | |
| | | |
| ALLETE Clean Energy | 58.6 | | 49.2 | | 37.9 | |
| | | |
| Corporate and Other | 11.7 | | 11.8 | | 13.0 | |
| Total Depreciation and Amortization | $242.2 | | $231.7 | | $217.8 | |
| Impairment of Property, Plant and Equipment | | | |
| ALLETE Clean Energy | — | | — | | $12.7 | |
| | | |
| | | |
Interest Expense (a) | | | |
| Regulated Operations | $58.1 | | $57.3 | | $58.5 | |
| | | |
| | | |
| ALLETE Clean Energy | 2.3 | | 1.5 | | 2.2 | |
| | | |
| Corporate and Other | 19.6 | | 13.2 | | 13.2 | |
| | | |
| Eliminations | (4.8) | | (2.9) | | (8.3) | |
| Total Interest Expense | $75.2 | | $69.1 | | $65.6 | |
| Equity Earnings | | | |
| Regulated Operations | $19.3 | | $21.3 | | $22.3 | |
| Corporate and Other | (0.6) | | (1.3) | | (0.2) | |
| Total Equity Earnings | $18.7 | | $20.0 | | $22.1 | |
| Income Tax Expense (Benefit) | | | |
| Regulated Operations | $(10.4) | $(16.6) | $(19.4) |
| | | |
| | | |
| ALLETE Clean Energy | (15.4) | (16.6) | | (23.0) | |
| | | |
| Corporate and Other | (5.4) | 6.3 | | (1.0) | |
| Total Income Tax Benefit | $(31.2) | $(26.9) | $(43.4) |
(a) Includes interest expense resulting from intercompany loan agreements and allocated to certain subsidiaries. The amounts are eliminated in consolidation.
| | | | | | | | | |
| As of December 31 | 2022 | 2021 | |
| Millions | | | |
| Assets | | | |
| Regulated Operations | $4,291.4 | | $4,289.4 | | |
| | | |
| | | |
| ALLETE Clean Energy | 1,873.3 | | 1,706.7 | | |
| | | |
| | | |
| Corporate and Other | 680.9 | | 426.2 | | |
| Total Assets | $6,845.6 | | $6,422.3 | | |
| Capital Expenditures | | | |
| Regulated Operations | $158.3 | | $166.8 | | |
| | | |
| | | |
| ALLETE Clean Energy | 2.2 | | 269.9 | | |
| | | |
| | | |
| Corporate and Other | 47.6 | | 39.7 | | |
| Total Capital Expenditures | $208.1 | | $476.4 | | |
ALLETE, Inc. 2022 Form 10-K
125
NOTE 15. QUARTERLY FINANCIAL DATA (UNAUDITED)
Information for any one quarterly period is not necessarily indicative of the results which may be expected for the year.
| | | | | | | | | | | | | | |
| Quarter Ended | Mar. 31 | Jun. 30 | Sept. 30 | Dec. 31 |
| Millions Except Earnings Per Share | | | | |
| 2022 | | | | |
| Operating Revenue | $383.5 | | $373.1 | | $388.3 | | $425.8 | |
| Operating Income | $53.4 | | $13.7 | | $33.4 | | $33.7 | |
| Net Income Attributable to ALLETE | $66.3 | | $37.6 | | $33.7 | | $51.7 | |
| Earnings Per Share of Common Stock | | | | |
| Basic | $1.24 | | $0.67 | | $0.59 | | $0.90 | |
| Diluted | $1.24 | | $0.67 | | $0.59 | | $0.90 | |
| 2021 | | | | |
| Operating Revenue | $339.2 | | $335.6 | | $345.4 | | $399.0 | |
| Operating Income | $42.0 | | $28.2 | | $31.1 | | $50.0 | |
| Net Income Attributable to ALLETE | $51.8 | | $27.9 | | $27.6 | | $61.9 | |
| Earnings Per Share of Common Stock | | | | |
| Basic | $0.99 | | $0.53 | | $0.53 | | $1.18 | |
| Diluted | $0.99 | | $0.53 | | $0.53 | | $1.18 | |
2020 (a) | | | | |
| Operating Revenue | $311.6 | | $243.2 | | $293.9 | | $320.4 | |
| Operating Income | $60.2 | | $12.7 | | $41.6 | | $23.7 | |
| Net Income Attributable to ALLETE | $66.3 | | $20.1 | | $40.7 | | $38.3 | |
| Earnings Per Share of Common Stock | | | | |
| Basic | $1.28 | | $0.39 | | $0.78 | | $0.74 | |
| Diluted | $1.28 | | $0.39 | | $0.78 | | $0.73 | |
(a) See Immaterial Revision to Prior Period in Note 1. Operations and Significant Accounting Policies.