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WAPA BPAT NF Montana OATT CROSSOVER BPAT.NWMT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT AVA SFP Montana OATT MATL.NWMT AVAT.NWMT 2022-01-012022-03-31 C001789 Dynasty Power Inc. PPW WAPA NF Montana OATT YTP CROSSOVER 2022-01-012022-03-31 C001789 Current Ad Valorem True-Up (South Dakota) - Docket GE98-001 2022-03-31 C001789 FAS 112 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2021-12-31 C001789 Avista Corporation NWMT AVA NF Montana OATT NWMTIMBALANC AVAT.NWMT 2022-01-012022-03-31 C001789 Montana Public Service Commission (Montana) - Docket 2017.9.78 - Order 7568 2021-12-31 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT SFP Montana OATT HARDIN MATL.NWMT 2022-01-012022-03-31 C001789 Bonneville Power Administration BPAT WAPA NF Montana OATT BPAT.NWMT GREATFALLS 2022-01-012022-03-31 C001789 Flow-through Income Taxes (Montana) 2021-12-31 C001789 BRYANT, CITY OF WAPA BRYANT LFP VOL 2 HURON 115 KV BUS BRYANT 25 KV 2022-01-012022-03-31 C001789 Transalta Energy Marketing (US) Inc. BPAT PPW NF Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 FAS 106 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT PACE SFP Montana OATT MATL.NWMT BRDY 2022-01-012022-03-31 C001789 Transalta Energy Marketing (US) Inc. BPAT PPW NF Montana OATT BPAT.NWMT BRDY 2022-01-012022-03-31 C001789 Flow-through Income Taxes (South Dakota) 2021-12-31 C001789 SIS Studies 2022-01-012022-03-31 C001789 Guzman Energy, LLC NWMT PPW NF Montana OATT COLSTRIP BRDY 2022-01-012022-03-31 C001789 SOUTH DAKOTA      2022-01-012022-03-31 C001789 Basin Electric Power Cooperative PPW NWMT NF Montana OATT YTP NWMT.SYSTEM 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. PACE NWMT NF Montana OATT BRDY MATL.NWMT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA PPW NF Montana OATT GLWND1 YTP 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. PACE NWMT SFP Montana OATT YTP MATL.NWMT 2022-01-012022-03-31 C001789 Unbilled Revenues (South Dakota) 2022-01-012022-03-31 C001789 Rounding      2022-01-012022-03-31 C001789 Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT SFP Montana OATT KERR MATL.NWMT 2022-01-012022-03-31 C001789 ferc:Quarter3Member Montana Operations 2022-01-012022-03-31 C001789 Dynasty Power Inc. PPW BPAT NF Montana OATT YTP BPAT.NWMT 2022-01-012022-03-31 C001789 BPA Residential Exchange Program (Montana) - Docket 2018.8.49 Order 7630; Annual Amortization 2022-01-012022-03-31 C001789 Shell Energy North America WAPA AVA NF Montana OATT CROSSOVER AVAT.NWMT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT PACE SFP Montana OATT MATL.NWMT YTP 2022-01-012022-03-31 C001789 FEA Studies 2022-01-012022-03-31 C001789 ferc:OtherUtilityMember 2022-03-31 C001789 FAC Studies 2022-01-012022-03-31 C001789 EDF Trading North America, LLC NWMT BPAT NF Montana OATT COLSTRIP BPAT.NWMT 2022-01-012022-03-31 C001789 Powerex Corporation PPW BPAT NF Montana OATT BRDY BPAT.NWMT 2022-01-012022-03-31 C001789 Aberdeen Manufactured Gas Plant (South Dakota) - Docket NG 11-003 2021-12-31 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT SFP Montana OATT COLSTRIP MATL.NWMT 2022-01-012022-03-31 C001789 Avista Corporation NWMT AVA NF Montana OATT COLSTRIP AVAT.NWMT 2022-01-012022-03-31 C001789 Shell Energy North America PPW BPAT NF Montana OATT YTP BPAT.NWMT 2022-01-012022-03-31 C001789 Basin Electric Power Cooperative NWMT PACE NF Montana OATT JUDITHGAP YTP 2022-01-012022-03-31 C001789 Guzman Energy, LLC BPAT PPW NF Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (Montana) 2022-01-012022-03-31 C001789 City of Great Falls Energy Keepers Inc. City of Great Falls FNO Montana OATT Kerr Various in Montana 2022-01-012022-03-31 C001789 Guzman Energy, LLC AVA PPW NF Montana OATT AVAT.NWMT BRDY 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT WAUW NF Montana OATT MATL.NWMT CROSSOVER 2022-01-012022-03-31 C001789 Cycle Power Partners, LLC NWMT PACE NF Montana OATT HORSESHOE JEFF 2022-01-012022-03-31 C001789 Macquarie Energy, LLC BPAT WAPA NF Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 ferc:Quarter1Member South Dakota Operations 2022-01-012022-03-31 C001789 Montana Public Service Commission Consumer Counsel Taxes (Montana) - Dockets 2017.9.78 and 2018.10.67 2021-12-31 C001789 Dynasty Power Inc. PPW PPW NF Montana OATT YTP BRDY 2022-01-012022-03-31 C001789 Powerex Corporation WAPA BPAT NF Montana OATT CROSSOVER BPAT.NWMT 2022-01-012022-03-31 C001789 Shell Energy North America BPAT PPW NF Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 Western Area Power Administration WAPA Malmstrom Air Force Base FNO Montana OATT Fort Peck West Great Falls, MT 2022-01-012022-03-31 C001789 Tax Cut Jobs Act Deferral (South Dakota) - Docket NG-0095 and GE17-003 2021-12-31 C001789 Shell Energy North America PPW AVA SFP Montana OATT YTP AVAT.NWMT 2022-01-012022-03-31 C001789 LANGFORD, CITY OF WAPA LANGFORD LFP VOL 2 HURON 115 KV BUS LANGFORD 12.5 KV 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA PPW SFP Montana OATT GLWND1 JEFF 2022-01-012022-03-31 C001789 Tax Cut Jobs Act Deferral (South Dakota) - Docket NG-0095 and GE17-003 2022-01-012022-03-31 C001789 Flow-through Income Taxes (South Dakota) 2022-03-31 C001789 Morgan Stanley Capital Group, Inc. WAUW NWMT SFP Montana OATT CROSSOVER MATL.NWMT 2022-01-012022-03-31 C001789 Avista Corporation AVA AVA SFP Montana OATT COLSTRIP AVAT.NWMT 2022-01-012022-03-31 C001789 Pension Plan (Montana) 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA PPW NF Montana OATT GLWND2 YTP 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA BPAT NF Montana OATT GLWND1 BPAT.NWMT 2022-01-012022-03-31 C001789 Guzman Energy, LLC BPAT PPW SFP Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. BPAT PPW SFP Montana OATT BPAT.NWMT JEFF 2022-01-012022-03-31 C001789 Montana Consumer Counsel Tax (Montana) - Docket 2018.10.67 - Order 7637 2022-01-012022-03-31 C001789 Line of Credit (Repayments) Borrowings, Net 2021-01-012021-03-31 C001789 Treasury Stock Activity 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA NWMT SFP Montana OATT GLWND2 NWMT.SYSTEM 2022-01-012022-03-31 C001789 Energy Keepers FIP NWMT BPAT OLF Montana OATT KERR BPAT.NWMT 2022-01-012022-03-31 C001789 Dynasty Power Inc. BPAT WAPA NF Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 Public Service Company of Colorado WAPA PPW NF Montana OATT CROSSOVER YTP 2022-01-012022-03-31 C001789 Market Monitoring & Compliance 2022-01-012022-03-31 C001789 Southwest Power Pool (SPP) SPP Various NF SCH 8 Various Various 2022-01-012022-03-31 C001789 Bonneville Power Admin OLF 2022-01-012022-03-31 C001789 ferc:AugustMember South Dakota Operations 2022-01-012022-03-31 C001789 Study of the Costs & Benefits of Customer Generators (Montana) 2022-03-31 C001789 Great Falls Public Schools Energy Keepers Inc. Great Falls Public Schools FNO Montana OATT Kerr Great Falls, MT 2022-01-012022-03-31 C001789 Avista NF 2022-01-012022-03-31 C001789 Montana Public Service Commission Consumer Counsel Taxes (Montana) - Dockets 2017.9.78 and 2018.10.67 2022-03-31 C001789 ferc:JuneMember South Dakota Operations 2022-01-012022-03-31 C001789 CTC QF Over/Under Collections (Montana) - Docket 97.9.90 and Docket 2001.1.15; Annual Amortization 2022-01-012022-03-31 C001789 ferc:SeptemberMember South Dakota Operations 2022-01-012022-03-31 C001789 ferc:OtherUtility3Member 2022-03-31 C001789 FAS 112 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-03-31 C001789 Magris Talc USA, Inc. Energy Keepers Inc. Imerys Talc America, Inc. FNO Montana OATT Kerr Three Forks, MT 2022-01-012022-03-31 C001789 Beartooth Electric Cooperative, Inc. WAPA Beartooth Electric Cooperative, Inc. FNO Montana OATT Fort Peck Various in Montana 2022-01-012022-03-31 C001789 Brookfield Renewable Trading and Marketing LP BPAT WAPA NF Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 The Energy Authority BPAT NWMT NF Montana OATT BPAT.NWMT NWMT.SYSTEM 2022-01-012022-03-31 C001789 2022-03-31 C001789 ferc:MarchMember South Dakota Operations 2022-01-012022-03-31 C001789 FAS 106 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-01-012022-03-31 C001789 Asset Retirement Obligation (Montana) 2021-12-31 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT NF Montana OATT KERR MATL.NWMT 2022-01-012022-03-31 C001789 General Mills Operations, LLC Talen Energy General Mills Operations, LLC FNO Montana OATT Colstrip Great Falls, MT 2022-01-012022-03-31 C001789 Atlas Power, LLC Tenaska Atlas Power, LLC FNO Montana OATT BPAT.NWMT Butte, MT 2022-01-012022-03-31 C001789 Guzman Energy, LLC PPW AVA SFP Montana OATT YTP AVAT.NWMT 2022-01-012022-03-31 C001789 Vigilante Elec. Coop OLF 2022-01-012022-03-31 C001789 The Energy Authority BPAT PPW SFP Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 Dynasty Power Inc. BPAT PPW NF Montana OATT BPAT.NWMT BRDY 2022-01-012022-03-31 C001789 Southwester Power Pool (MT) FNS 2022-01-012022-03-31 C001789 REC Silicon Company Morgan Stanley REC Silicon Company FNO Montana OATT Hardin  Butte, MT 2022-01-012022-03-31 C001789 ferc:FebruaryMember Montana Operations 2022-01-012022-03-31 C001789 Guzman Energy, LLC PPW AVA SFP Montana OATT BRDY AVAT.NWMT 2022-01-012022-03-31 C001789 SOUTH DAKOTA 2022-01-012022-03-31 C001789 ferc:MarchMember Montana Operations 2022-01-012022-03-31 C001789 Current Ad Valorem True-Up (South Dakota) - Docket GE98-001 2021-12-31 C001789 Morgan Stanley Capital Group, Inc. GWA PPW SFP Montana OATT GLWND2 JEFF 2022-01-012022-03-31 C001789 Mercuria Energy America, LLC PPW BPAT NF Montana OATT YTP BPAT.NWMT 2022-01-012022-03-31 C001789 Barretts Minerals, Inc. Energy Keepers inc. Barretts Minerals, Inc. FNO Montana OATT Kerr Dillon, MT 2022-01-012022-03-31 C001789 The Energy Authority BPAT NWMT NF Montana OATT BPAT.NWMT MATL.NWMT 2022-01-012022-03-31 C001789 FAS 106 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2021-12-31 C001789 ferc:DistributionPlantMemberferc:ElectricUtilityMember 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA PPW NF Montana OATT GLWND1 BRDY 2022-01-012022-03-31 C001789 Powerex Corporation PPW BPAT NF Montana OATT YTP BPAT.NWMT 2022-01-012022-03-31 C001789 ferc:CommonUtilityMember 2022-03-31 C001789 Field Inventory (South Dakota) - Docket EL 14-106 2021-12-31 C001789 Morgan Stanley Capital Group, Inc. NWMT GWA NF Montana OATT MATL.NWMT GLWND1 2022-01-012022-03-31 C001789 Ash Grove Cement Energy Keepers Inc. Ash Grove Cement FNO Montana OATT Kerr Clancy, MT 2022-01-012022-03-31 C001789 ferc:Quarter3Member South Dakota Operations 2022-01-012022-03-31 C001789 Compensated Absences (Montana) - Docket 97.11.219 2022-01-012022-03-31 C001789 Natural Gas Regulatory Deferrals (Montana) 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT AVA NF Montana OATT MATL.NWMT AVAT.NWMT 2022-01-012022-03-31 C001789 Avista Corporation AVA AVA NF Montana OATT COLSTRIP AVAT.NWMT 2022-01-012022-03-31 C001789 Rainbow Electric Marketing Corp. BPAT PPW NF Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA NWMT NF Montana OATT GLWND1 MATL.NWMT 2022-01-012022-03-31 C001789 ferc:Quarter2Member Montana Operations 2022-01-012022-03-31 C001789 Black Hills Power Inc. NWMT PPW NF Montana OATT COLSTRIP YTP 2022-01-012022-03-31 C001789 Day Ahead & Real Time Admin 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (South Dakota) 2022-01-012022-03-31 C001789 Basin Creek Capital Lease (Montana) 2022-01-012022-03-31 C001789 Western Area Power Administration WAPA WAPA SFP Montana OATT CROSSOVER GREATFALLS 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. WAPA PPW NF Montana OATT GREATFALLS JEFF 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA PPW SFP Montana OATT GLWND2 BRDY 2022-01-012022-03-31 C001789 Macquarie Energy, LLC PPW WAPA SFP Montana OATT YTP CROSSOVER 2022-01-012022-03-31 C001789 ferc:GasUtilityMember 2021-01-012021-03-31 C001789 Transalta Energy Marketing (US) Inc. PPW WAPA NF Montana OATT YTP CROSSOVER 2022-01-012022-03-31 C001789 Compensated Absences (Montana) - Docket 97.11.219 2022-03-31 C001789 Guzman Energy, LLC AVA PPW NF Montana OATT AVAT.NWMT YTP 2022-01-012022-03-31 C001789 Montana State University - Bozeman WAPA Montana State University - Bozeman FNO Montana OATT Fort Peck West Great Falls, MT 2022-01-012022-03-31 C001789 Asset Retirement Obligation (South Dakota) 2022-03-31 C001789 GCC Three Forks, LLC Energy Keepers Inc. GCC Three Forks, LLC FNO Montana OATT Kerr Three Forks, MT 2022-01-012022-03-31 C001789 2021-01-012021-03-31 C001789 Montana Resources Energy Keepers Inc. Montana Resources FNO Montana OATT BPAT.NWMT&Kerr Butte, MT 2022-01-012022-03-31 C001789 2022-01-012022-03-31 C001789 Basin Electric Power Cooperative WAPA WAPA LFP Montana OATT CROSSOVER GREATFALLS 2022-01-012022-03-31 C001789 Western Area Power Administration WAPA NWMT NF Montana OATT GREATFALLS NWMT.SYSTEM 2022-01-012022-03-31 C001789 Powerex Corporation BPAT PPW NF Montana OATT BPAT.NWMT BRDY 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. BPAT GWA NF Montana OATT BPAT.NWMT GLWND2 2022-01-012022-03-31 C001789 ferc:ElectricUtilityMember 2021-01-012021-03-31 C001789 FEA Studiesferc:GenerationStudiesMember 2022-01-012022-03-31 C001789 Portland General Electric Company NWMT BPAT NF Montana OATT COLSTRIP BPAT.NWMT 2022-01-012022-03-31 C001789 Black Hills Power Inc. WAPA PPW NF Montana OATT CROSSOVER YTP 2022-01-012022-03-31 C001789 Asset Retirement Obligation (Montana) 2022-03-31 C001789 Tenaska Power Services Co. NWMT BPAT NF Montana OATT COLSTRIP BPAT.NWMT 2022-01-012022-03-31 C001789 Naturener Power Watch, LLC GWA GWA SFP Montana OATT GLWND1 GLWND2 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (Montana) 2021-12-31 C001789 Idaho Power Company PPW IPCO SFP Montana OATT JEFF TNDY 2022-01-012022-03-31 C001789 Dynasty Power Inc. WAPA PPW NF Montana OATT CROSSOVER BRDY 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. AVA NWMT SFP Montana OATT AVAT.NWMT MATL.NWMT 2022-01-012022-03-31 C001789 ferc:HydraulicProductionPlantConventionalMemberferc:ElectricUtilityMember 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (Montana) 2022-03-31 C001789 Morgan Stanley Capital Group, Inc. WAPA PPW NF Montana OATT GREATFALLS BRDY 2022-01-012022-03-31 C001789 Aspen Air U.S., LLC Talen Energy Aspen Air Corporation FNO Montana OATT Colstrip  Billings, MT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA PPW NF Montana OATT GLWND2 BRDY 2022-01-012022-03-31 C001789 Montana Consumer Counsel Tax (Montana) - Docket 2018.10.67 - Order 7637 2021-12-31 C001789 ferc:OctoberMember South Dakota Operations 2022-01-012022-03-31 C001789 Natural Gas Transmission Verification Program (Montana) - Docket D2016.11.88 2022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA NWMT NF Montana OATT GLWND2 MATL.NWMT 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (South Dakota) 2022-03-31 C001789 ExxonMobil Corporation Talen Energy ExxonMobil Corporation FNO Montana OATT Colstrip Billings, MT 2022-01-012022-03-31 C001789 ferc:TransmissionPlantMemberferc:ElectricUtilityMember 2022-01-012022-03-31 C001789 CTC QF Over/Under Collections (Montana) - Docket 97.9.90 and Docket 2001.1.15; Annual Amortization 2022-03-31 C001789 Guzman Energy, LLC PPW AVA NF Montana OATT YTP AVAT.NWMT 2022-01-012022-03-31 C001789 Treasury Stock Activity 2021-01-012021-03-31 C001789 Sibanye-Stillwater Energy Keepers Inc. Stillwater Mining Company FNO Montana OATT Kerr Various in Montana 2022-01-012022-03-31 C001789 ferc:OtherProductionPlantMemberferc:ElectricUtilityMember 2022-01-012022-03-31 C001789 Montana Public Service Commission (Montana) - Docket 2017.9.78 - Order 7568 2022-03-31 C001789 Macquarie Energy, LLC NWMT BPA NF Montana OATT BGI BPAT.NWMT 2022-01-012022-03-31 C001789 The Energy Authority BPAT PPW NF Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (Montana) 2022-01-012022-03-31 C001789 Energy Keepers Inc. NWMT PACE SFP Montana OATT KERR BRDY 2022-01-012022-03-31 C001789 Transalta Energy Marketing (US) Inc. BPAT PPW NF Montana OATT BPAT.NWMT JEFF 2022-01-012022-03-31 C001789 Black Hills Power Inc. BPAT PPW NF Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 Aberdeen Manufactured Gas Plant (South Dakota) - Docket NG 11-003 2022-03-31 C001789 ferc:NovemberMember South Dakota Operations 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT NF Montana OATT COLSTRIP MATL.NWMT 2022-01-012022-03-31 C001789 ferc:DecemberMember South Dakota Operations 2022-01-012022-03-31 C001789 Black Hills Power Inc. AVA PPW NF Montana OATT AVAT.NWMT YTP 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (South Dakota) 2022-01-012022-03-31 C001789 Guzman Energy, LLC PPW BPAT NF Montana OATT BRDY BPAT.NWMT 2022-01-012022-03-31 C001789 Montana Operationsferc:Quarter1Member 2022-01-012022-03-31 C001789 ferc:TransmissionStudiesMember Line Interconnection Studies 2022-01-012022-03-31 C001789 Basin Electric Power Cooperative NWMT PPW NF Montana OATT COLSTRIP YTP 2022-01-012022-03-31 C001789 Town of Philipsburg Town of Philipsburg Town of Philipsburg FNO Montana OATT Philipsburg Substation Philipsburg, MT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA NWMT NF Montana OATT GLWND1 NWMT.SYSTEM 2022-01-012022-03-31 C001789 Rainbow Electric Marketing Corp. PPW WAPA NF Montana OATT YTP CROSSOVER 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. BPAT PPW NF Montana OATT BPAT.NWMT JEFF 2022-01-012022-03-31 C001789 Shell Energy North America PPW AVA NF Montana OATT BRDY AVAT.NWMT 2022-01-012022-03-31 C001789 Shell Energy North America WAPA PPW NF Montana OATT CROSSOVER JEFF 2022-01-012022-03-31 C001789 ferc:JanuaryMember Montana Operations 2022-01-012022-03-31 C001789 Basin Electric Power Cooperative Basin Electric & WAPA Basin Electric Power Cooperative FNO Montana OATT Crossover  Various NWMT & WAUW 2022-01-012022-03-31 C001789 Manufactured Gas Plants (South Dakota) - Docket NG 11-003 2022-01-012022-03-31 C001789 Phillips 66 Company Shell Energy Phillips 66 Company FNO Montana OATT BPAT.NWMT Various in Montana 2022-01-012022-03-31 C001789 ferc:GasUtilityMember 2022-03-31 C001789 Montana Public Service Commission (Montana) - Docket 2017.9.78 - Order 7568 2022-01-012022-03-31 C001789 ScheduleRegionalTransmissionServiceRevenuesAbstract 2022-01-012022-03-31 C001789 Compensated Absences (Montana) - Docket 97.11.219 2021-12-31 C001789 Guzman Energy, LLC PPW BPAT NF Montana OATT YTP BPAT.NWMT 2022-01-012022-03-31 C001789 Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization 2022-01-012022-03-31 C001789 West Central Elect COOP FNS 2022-01-012022-03-31 C001789 Bonneville Power Admin NF 2022-01-012022-03-31 C001789 Other 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA WAPA NF Montana OATT GLWND1 CROSSOVER 2022-01-012022-03-31 C001789 Basin Electric Power Cooperative PPW WAPA NF Montana OATT YTP GREATFALLS 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT PACE NF Montana OATT MATL.NWMT JEFF 2022-01-012022-03-31 C001789 ferc:GenerationStudiesMember 2022-01-012022-03-31 C001789 Rainbow Electric Marketing Corp. NWMT PPW NF Montana OATT COLSTRIP YTP 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. BPAT NWMT NF Montana OATT BPAT.NWMT MATL.NWMT 2022-01-012022-03-31 C001789 Common Stock Dividend 2021-01-012021-03-31 C001789 Morgan Stanley Capital Group, Inc. WAUW NWMT NF Montana OATT CROSSOVER MATL.NWMT 2022-01-012022-03-31 C001789 Public Service Company of Colorado PPW WAPA NF Montana OATT YTP CROSSOVER 2022-01-012022-03-31 C001789 Rainbow Electric Marketing Corp. BPAT WAPA NF Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 Talen Energy Marketing, LLC NWMT BPAT LFP Montana OATT GTFALLSNWMT BPAT.NWMT 2022-01-012022-03-31 C001789 Western Area Power Administration BPAT WAPA NF Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 Powerex Corporation BPAT WAPA NF Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 The Energy Authority BPAT WAPA NF Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 The Energy Authority WAPA BPAT NF Montana OATT CROSSOVER BPAT.NWMT 2022-01-012022-03-31 C001789 Guzman Energy, LLC BPAT AVA NF Montana OATT BPAT.NWMT AVAT.NWMT 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (South Dakota) 2022-03-31 C001789 Idaho Power Company AVA PPW SFP Montana OATT AVAT.NWMT BRDY 2022-01-012022-03-31 C001789 Natural Gas Regulatory Deferrals (Montana) 2022-03-31 C001789 EDF Trading North America, LLC NWMT PPW NF Montana OATT COLSTRIP BRDY 2022-01-012022-03-31 C001789 Benefis Health Systems Energy Keepers inc. Benefis Health Systems FNO Montana OATT Kerr Various in Montana 2022-01-012022-03-31 C001789 Transalta Energy Marketing (US) Inc. BPAT WAPA NF Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 2021-03-31 C001789 Rainbow Electric Marketing Corp. AVA WAPA NF Montana OATT AVAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 Pension Plan (South Dakota) 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT NF Montana OATT HARDIN MATL.NWMT 2022-01-012022-03-31 C001789 Manufactured Gas Plants (South Dakota) - Docket NG 11-003 2021-12-31 C001789 Morgan Stanley Capital Group, Inc. WAPA BPAT NF Montana OATT GREATFALLS BPAT.NWMT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT GWA NF Montana OATT MATL.NWMT GLWND2 2022-01-012022-03-31 C001789 Roseburg Forest Products Company Talen Energy Roseburg Forest Products Company FNO Montana OATT Colstrip Missoula, MT 2022-01-012022-03-31 C001789 ferc:MayMember South Dakota Operations 2022-01-012022-03-31 C001789 Montana Public Service Commission Consumer Counsel Taxes (Montana) - Dockets 2017.9.78 and 2018.10.67 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA AVA NF Montana OATT GLWND2 AVAT.NWMT 2022-01-012022-03-31 C001789 ferc:JanuaryMember South Dakota Operations 2022-01-012022-03-31 C001789 Flow-through Income Taxes (Montana) 2022-01-012022-03-31 C001789 Southwest Power Pool (SPP) SPP Various LFP SCH 7 Various Various 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (South Dakota) 2021-12-31 C001789 Morgan Stanley Capital Group, Inc. PPW BPAT NF Montana OATT BRDY BPAT.NWMT 2022-01-012022-03-31 C001789 ferc:GasUtilityMember 2022-01-012022-03-31 C001789 Flow-through Income Taxes (South Dakota) 2022-01-012022-03-31 C001789 Macquarie Energy, LLC NWMT BPA SFP Montana OATT BGI BPAT.NWMT 2022-01-012022-03-31 C001789 Pension Plan (South Dakota) 2021-12-31 C001789 Basin Electric Power Cooperative PPW WAPA NF Montana OATT YTP CROSSOVER 2022-01-012022-03-31 C001789 EDF Trading North America, LLC BPAT NWMT NF Montana OATT BPAT.NWMT NWMT.SYSTEM 2022-01-012022-03-31 C001789 ferc:GenerationStudiesMember FAC Studies 2022-01-012022-03-31 C001789 Other Noncash Charges to Income, Net 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA NWMT NF Montana OATT GLWND2 NWMT.SYSTEM 2022-01-012022-03-31 C001789 Guzman Energy, LLC NWMT AVA NF Montana OATT NWMTIMBALANC AVAT.NWMT 2022-01-012022-03-31 C001789 GROTON, CITY OF WAPA GROTON LFP VOL 2 HURON 115 KV BUS GROTON 69 KV 2022-01-012022-03-31 C001789 Rainbow Electric Marketing Corp. BPAT PPW SFP Montana OATT BPAT.NWMT BRDY 2022-01-012022-03-31 C001789 Shell Energy North America WAPA PPW NF Montana OATT CROSSOVER BRDY 2022-01-012022-03-31 C001789 Calumet Refining, LLC Talen Energy Calumet Montana Refining Company, Inc. FNO Montana OATT Colstrip Great Falls, MT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. WAPA PPW NF Montana OATT GREATFALLS YTP 2022-01-012022-03-31 C001789 The Energy Authority NWMT PPW NF Montana OATT COLSTRIP BRDY 2022-01-012022-03-31 C001789 Rainbow Electric Marketing Corp. NWMT PPW SFP Montana OATT COLSTRIP YTP 2022-01-012022-03-31 C001789 Macquarie Energy, LLC NWMT PACE NF Montana OATT TFALLS BRDY 2022-01-012022-03-31 C001789 Optional Studies 2022-01-012022-03-31 C001789 South Dakota Operations 2022-01-012022-03-31 C001789 ScheduleTransmissionOfElectricityByIsoOrRtoAbstract 2022-01-012022-03-31 C001789 Amortization of 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT SFP Montana OATT CANYONFERRY MATL.NWMT 2022-01-012022-03-31 C001789 Natural Gas Regulatory Deferrals (Montana) 2021-12-31 C001789 Pension Plan (Montana) 2022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT PACE NF Montana OATT MATL.NWMT BRDY 2022-01-012022-03-31 C001789 Pension Plan (South Dakota) 2022-03-31 C001789 FAS 112 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-01-012022-03-31 C001789 Other 2021-01-012021-03-31 C001789 EDF Trading North America, LLC NWMT BPAT SFP Montana OATT COLSTRIP BPAT.NWMT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA PPW SFP Montana OATT GLWND1 BRDY 2022-01-012022-03-31 C001789 EDF Trading North America, LLC BPAT NWMT NF Montana OATT BPAT.NWMT COLSTRIP 2022-01-012022-03-31 C001789 ConocoPhillips BPAT WAPA NF Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 Southwest Power Pool (SPP) SPP Various FNS SCH 9 Various Various 2022-01-012022-03-31 C001789 Cycle Power Partners, LLC NWMT PACE NF Montana OATT HORSESHOE BRDY 2022-01-012022-03-31 C001789 EDF Trading North America, LLC NWMT NWMT NF Montana OATT COLSTRIP MATL.NWMT 2022-01-012022-03-31 C001789 Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization 2021-12-31 C001789 Morgan Stanley Capital Group, Inc. GWA PPW NF Montana OATT GLWND1 JEFF 2022-01-012022-03-31 C001789 ferc:FebruaryMember South Dakota Operations 2022-01-012022-03-31 C001789 Deferred Gas Storage Sales (Montana) - Docket D2001.1.1; Amortization 2001 - 2039 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. BPAT PPW SFP Montana OATT BPAT.NWMT BRDY 2022-01-012022-03-31 C001789 Energy Keepers Inc. NWMT PACE SFP Montana OATT KERR JEFF 2022-01-012022-03-31 C001789 Other Noncash Charges to Income, Net 2021-01-012021-03-31 C001789 Line of Credit (Repayments) Borrowings, Net 2022-01-012022-03-31 C001789 EDF Trading North America, LLC AVA AVA NF Montana OATT COLSTRIP AVAT.NWMT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT NF Montana OATT NWMTIMBALANC BPAT.NWMT 2022-01-012022-03-31 C001789 Shell Energy North America BPAT PPW NF Montana OATT BPAT.NWMT BRDY 2022-01-012022-03-31 C001789 Supply: 2022-01-012022-03-31 C001789 CHS, Inc. Morgan Stanley CHS, Inc. FNO Montana OATT MATL.NWMT Various in Montana 2022-01-012022-03-31 C001789 ferc:TransmissionStudiesMember FAC Studies 2022-01-012022-03-31 C001789 Brookfield Renewable Trading and Marketing LP NWMT WAPA NF Montana OATT COLSTRIP CROSSOVER 2022-01-012022-03-31 C001789 Big Horn County Electric Coop. Inc. WAPA Big Horn County Electric Coop. Inc. FNO Montana OATT Various & Great Falls  Various in Montana 2022-01-012022-03-31 C001789 Transalta Energy Marketing (US) Inc. WAPA BPAT NF Montana OATT CROSSOVER BPAT.NWMT 2022-01-012022-03-31 C001789 Tax Cut Jobs Act Deferral (South Dakota) - Docket NG-0095 and GE17-003 2022-03-31 C001789 Basin Electric Power Cooperative NWMT PACE NF Montana OATT BGI YTP 2022-01-012022-03-31 C001789 Powerex Corporation BPAT PPW NF Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT NF Montana OATT HARDIN BPAT.NWMT 2022-01-012022-03-31 C001789 Transalta Energy Marketing (US) Inc. PPW BPAT NF Montana OATT YTP BPAT.NWMT 2022-01-012022-03-31 C001789 Dynasty Power Inc. BPAT PPW NF Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT NF Montana OATT MATL.NWMT BPAT.NWMT 2022-01-012022-03-31 C001789 ferc:SteamProductionPlantMemberferc:ElectricUtilityMember 2022-01-012022-03-31 C001789 EDF Trading North America, LLC NWMT NWMT NF Montana OATT COLSTRIP COLSTRIP 2022-01-012022-03-31 C001789 ferc:OtherUtility2Member 2022-03-31 C001789 Western Area Power Administration WAPA WAPA SFP Montana OATT GREATFALLS CROSSOVER 2022-01-012022-03-31 C001789 Montana Operations 2022-01-012022-03-31 C001789 Basin Electric Power Cooperative Morgan Stanley, Talen & WAPA Basin Electric Power Cooperative FNO Montana OATT Various in Montana Various NWMT & WAUW 2022-01-012022-03-31 C001789 Other 2022-01-012022-03-31 C001789 Field Inventory (South Dakota) - Docket EL 14-106 2022-03-31 C001789 CTC QF Over/Under Collections (Montana) - Docket 97.9.90 and Docket 2001.1.15; Annual Amortization 2021-12-31 C001789 ferc:GeneralPlantMemberferc:ElectricUtilityMember 2022-01-012022-03-31 C001789 Shell Energy North America BPAT WAPA NF Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 BPA Residential Exchange Program (Montana) - Docket 2018.8.49 Order 7630; Annual Amortization 2022-03-31 C001789 Manufactured Gas Plants (South Dakota) - Docket NG 11-003 2022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT NF Montana OATT KERR BPAT.NWMT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. WAPA AVA NF Montana OATT GREATFALLS AVAT.NWMT 2022-01-012022-03-31 C001789 EDF Trading North America, LLC NWMT PPW NF Montana OATT COLSTRIP YTP 2022-01-012022-03-31 C001789 2021-12-31 C001789 Energy Keepers Inc. NWMT BPAT NF Montana OATT KERR BPAT.NWMT 2022-01-012022-03-31 C001789 Seattle City Light NF 2022-01-012022-03-31 C001789 The Energy Authority PPW BPAT NF Montana OATT YTP BPAT.NWMT 2022-01-012022-03-31 C001789 Shell Energy North America PPW PPW NF Montana OATT YTP BRDY 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. BPAT PPW NF Montana OATT BPAT.NWMT BRDY 2022-01-012022-03-31 C001789 Shell Energy North America PPW AVA NF Montana OATT YTP AVAT.NWMT 2022-01-012022-03-31 C001789 ferc:TransmissionStudiesMember SIS Studies 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA PPW NF Montana OATT GLWND2 JEFF 2022-01-012022-03-31 C001789 Amortization of 2021-01-012021-03-31 C001789 PacifiCorp PPW NWMT NF Montana OATT MLCK JEFF 2022-01-012022-03-31 C001789 Brookfield Renewable Trading and Marketing LP BPAT WAPA SFP Montana OATT BPAT.NWMT CROSSOVER 2022-01-012022-03-31 C001789 Energy Keepers Inc. NWMT BPAT LFP Montana OATT KERR BPAT.NWMT 2022-01-012022-03-31 C001789 Shell Energy North America NWMT BPAT NF Montana OATT KERR BPAT.NWMT 2022-01-012022-03-31 C001789 Basin Creek Capital Lease (Montana) 2021-12-31 C001789 Morgan Stanley Capital Group, Inc. GWA BPAT SFP Montana OATT GLWND1 BPAT.NWMT 2022-01-012022-03-31 C001789 Montana Operationsferc:Quarter4Member 2022-01-012022-03-31 C001789 Energy Keepers Inc. PPW BPAT SFP Montana OATT YTP BPAT.NWMT 2022-01-012022-03-31 C001789 Line Interconnection Studies 2022-01-012022-03-31 C001789 Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization 2022-03-31 C001789 Guzman Energy, LLC PPW BPAT SFP Montana OATT YTP BPAT.NWMT 2022-01-012022-03-31 C001789 The Energy Authority PPW BPAT SFP Montana OATT YTP BPAT.NWMT 2022-01-012022-03-31 C001789 Current Ad Valorem True-Up (South Dakota) - Docket GE98-001 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT PACE NF Montana OATT MATL.NWMT YTP 2022-01-012022-03-31 C001789 Bonneville Power Administration BPA  Bonneville Power Administration FNO Montana OATT BPAT.NWMT    Various in Montana 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT NF Montana OATT COLSTRIP BPAT.NWMT 2022-01-012022-03-31 C001789 East River FNS 2022-01-012022-03-31 C001789 Energy Keepers Inc. NWMT BPAT SFP Montana OATT KERR BPAT.NWMT 2022-01-012022-03-31 C001789 ferc:JulyMember South Dakota Operations 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (Montana) 2022-03-31 C001789 Unbilled Revenues (South Dakota) 2022-03-31 C001789 Morgan Stanley Capital Group, Inc. WAPA WAPA NF Montana OATT GREATFALLS CROSSOVER 2022-01-012022-03-31 C001789 ferc:ElectricUtilityMember 2022-03-31 C001789 Excess Deferred Income Taxes (Montana) 2021-12-31 C001789 Energy Keepers Inc. NWMT PACE NF Montana OATT KERR BRDY 2022-01-012022-03-31 C001789 Macquarie Energy, LLC NWMT WAPA SFP Montana OATT COLSTRIP CROSSOVER 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. AVA NWMT NF Montana OATT AVAT.NWMT MATL.NWMT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. BPAT GWA NF Montana OATT BPAT.NWMT GLWND1 2022-01-012022-03-31 C001789 Macquarie Energy, LLC NWMT BPAT NF Montana OATT TFALLS BPAT.NWMT 2022-01-012022-03-31 C001789 Unbilled Revenues (South Dakota) 2021-12-31 C001789 ferc:ElectricUtilityMember 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA AVA NF Montana OATT GLWND1 AVAT.NWMT 2022-01-012022-03-31 C001789 Energy Keepers Inc. NWMT AVA NF Montana OATT KERR AVAT.NWMT 2022-01-012022-03-31 C001789 Debt Financing Costs 2021-01-012021-03-31 C001789 Rainbow Electric Marketing Corp. AVA PPW NF Montana OATT AVAT.NWMT YTP 2022-01-012022-03-31 C001789 MONTANA POINT-TO-POINT      2022-01-012022-03-31 C001789 Energy Keepers Inc. NWMT PACE SFP Montana OATT KERR YTP 2022-01-012022-03-31 C001789 (Less) (449.1) Provision for Rate Refunds 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. BPAT NWMT SFP Montana OATT BPAT.NWMT MATL.NWMT 2022-01-012022-03-31 C001789 Study of the Costs & Benefits of Customer Generators (Montana) 2021-12-31 C001789 Asset Retirement Obligation (South Dakota) 2021-12-31 C001789 Morgan Stanley Capital Group, Inc. GWA BPAT NF Montana OATT GLWND2 BPAT.NWMT 2022-01-012022-03-31 C001789 Flow-through Income Taxes (Montana) 2022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT SFP Montana OATT MATL.NWMT BPAT.NWMT 2022-01-012022-03-31 C001789 Basin Electric Power Cooperative WAPA PPW NF Montana OATT CROSSOVER YTP 2022-01-012022-03-31 C001789 Deferred Gas Storage Sales (Montana) - Docket D2001.1.1; Amortization 2001 - 2039 2021-12-31 C001789 Common Stock Dividend 2022-01-012022-03-31 C001789 2020-12-31 C001789 Debt Financing Costs 2022-01-012022-03-31 C001789 Optional Studiesferc:GenerationStudiesMember 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. GWA BPAT SFP Montana OATT GLWND2 BPAT.NWMT 2022-01-012022-03-31 C001789 Basin Creek Capital Lease (Montana) 2022-03-31 C001789 Bonneville Power Administration BPAT PPW NF Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 ferc:OtherUtilityMember 2022-01-012022-03-31 C001789 Asset Retirement Obligation (Montana) 2022-01-012022-03-31 C001789 The Energy Authority BPAT PPW NF Montana OATT BPAT.NWMT BRDY 2022-01-012022-03-31 C001789 Guzman Energy, LLC PPW PPW NF Montana OATT YTP BRDY 2022-01-012022-03-31 C001789 ferc:GenerationStudiesMember SIS Studies 2022-01-012022-03-31 C001789 EDF Trading North America, LLC NWMT PPW SFP Montana OATT COLSTRIP BRDY 2022-01-012022-03-31 C001789 Guzman Energy, LLC BPAT PPW NF Montana OATT BPAT.NWMT BRDY 2022-01-012022-03-31 C001789 Shell Energy North America PPW WAPA NF Montana OATT BRDY CROSSOVER 2022-01-012022-03-31 C001789 Talen Montana, LLC Avista Energy Colstrip Steam Electric Station FNO Montana OATT Colstrip Nichols Pump Sub 2022-01-012022-03-31 C001789 The Energy Authority PPW BPAT NF Montana OATT BRDY BPAT.NWMT 2022-01-012022-03-31 C001789 Southwest Power Pool (SD) FNS 2022-01-012022-03-31 C001789 Suiza Dairy Group, LLC Talen Energy Suiza Dairy Group, LLC FNO Montana OATT Colstrip Various in Montana 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT GWA NF Montana OATT COLSTRIP GLWND1 2022-01-012022-03-31 C001789 Asset Retirement Obligation (South Dakota) 2022-01-012022-03-31 C001789 Natural Gas Transmission Verification Program (Montana) - Docket D2016.11.88 2021-12-31 C001789 Natural Gas Transmission Verification Program (Montana) - Docket D2016.11.88 2022-01-012022-03-31 C001789 Montana Consumer Counsel Tax (Montana) - Docket 2018.10.67 - Order 7637 2022-03-31 C001789 ferc:AprilMember South Dakota Operations 2022-01-012022-03-31 C001789 Bonneville Power Administration BPAT PPW NF Montana OATT BPAT.NWMT BRDY 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT WAUW NF Montana OATT MATL.NWMT GREATFALLS 2022-01-012022-03-31 C001789 Guzman Energy, LLC NWMT PPW NF Montana OATT COLSTRIP YTP 2022-01-012022-03-31 C001789 Western Area Power Administration NWMT WAPA NF Montana OATT CANYONFERRY CROSSOVER 2022-01-012022-03-31 C001789 Transalta Energy Marketing (US) Inc. WAPA PPW NF Montana OATT CROSSOVER BRDY 2022-01-012022-03-31 C001789 Dynasty Power Inc. PPW BPAT NF Montana OATT BRDY BPAT.NWMT 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. NWMT PACE SFP Montana OATT MATL.NWMT JEFF 2022-01-012022-03-31 C001789 Field Inventory (South Dakota) - Docket EL 14-106 2022-01-012022-03-31 C001789 Excess Deferred Income Taxes (South Dakota) 2021-12-31 C001789 Line of Credit (Repayments) Borrowings, Net 2022-01-012022-03-31 C001789 Study of the Costs & Benefits of Customer Generators (Montana) 2022-01-012022-03-31 C001789 Energy Keepers Inc. BPAT PPW SFP Montana OATT BPAT.NWMT YTP 2022-01-012022-03-31 C001789 MONTANA 2022-01-012022-03-31 C001789 ferc:IntangiblePlantMemberferc:ElectricUtilityMember 2022-01-012022-03-31 C001789 Investment in Equity Securities 2022-01-012022-03-31 C001789 Morgan Stanley Capital Group, Inc. WAUW NWMT NF Montana OATT GREATFALLS MATL.NWMT 2022-01-012022-03-31 C001789 MONTANA CHOICE TRANSMISSION      2022-01-012022-03-31 C001789 Sun River Elect Coop OLF 2022-01-012022-03-31 C001789 Shell Energy North America WAPA BPAT NF Montana OATT CROSSOVER BPAT.NWMT 2022-01-012022-03-31 C001789 ferc:CommonPlantElectricMemberferc:ElectricUtilityMember 2022-01-012022-03-31 C001789 ferc:TransmissionStudiesMember 2022-01-012022-03-31 C001789 Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization 2021-12-31 C001789 BPA Residential Exchange Program (Montana) - Docket 2018.8.49 Order 7630; Annual Amortization 2021-12-31 C001789 Western Area Power Administration WAPA Western Area Power Administration FNO Montana OATT Crossover Various NWMT & WAUW 2022-01-012022-03-31 C001789 ferc:Quarter2Member South Dakota Operations 2022-01-012022-03-31 C001789 Tenaska Power Services Co. NWMT PPW SFP Montana OATT COLSTRIP YTP 2022-01-012022-03-31 C001789 Deferred Gas Storage Sales (Montana) - Docket D2001.1.1; Amortization 2001 - 2039 2022-03-31 C001789 ferc:OtherUtilityMember 2021-01-012021-03-31 C001789 Aberdeen Manufactured Gas Plant (South Dakota) - Docket NG 11-003 2022-01-012022-03-31 utr:MW xbrli:pure ns:year utr:MWh iso4217:USD
THIS FILING IS
Item 1:
An Initial (Original) Submission
OR
Resubmission No.

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature
Exact Legal Name of Respondent (Company)

NorthWestern Corporation
Year/Period of Report

End of:
2022
/
Q1


INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

  1. Purpose

    FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
  2. Who Must Submit

    Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).

    Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
    1. one million megawatt hours of total annual sales,
    2. 100 megawatt hours of annual sales for resale,
    3. 500 megawatt hours of annual power exchanges delivered, or
    4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).
  3. What and Where to Submit

    1. Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
    2. The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
    3. Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
      Secretary
      Federal Energy Regulatory Commission 888 First Street, NE
      Washington, DC 20426
    4. For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

      The CPA Certification Statement should:
      1. Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and
      2. Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

        Schedules
        Pages
        Comparative Balance Sheet 110-113
        Statement of Income 114-117
        Statement of Retained Earnings 118-119
        Statement of Cash Flows 120-121
        Notes to Financial Statements 122-123
    5. The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.

      “In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.

      Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
    6. Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
    7. Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.
  4. When to Submit

    FERC Forms 1 and 3-Q must be filed by the following schedule:

    1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
    2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
  5. Where to Send Comments on Public Reporting Burden.

    The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.

    Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

  1. Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
  2. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
  3. Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
  4. For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
  5. Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
  6. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
  7. For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
  8. Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
  9. Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
  10. Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.
Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS
  1. Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
  2. Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

  1. ’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
  2. 'Person' means an individual or a corporation;
  3. 'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;
  1. 'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......
  1. "project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered
  1. 'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.
  1. Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10
"Sec. 309.
  1. The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).


FERC FORM NO.
1/3-Q

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER
Identification
01 Exact Legal Name of Respondent

NorthWestern Corporation
02 Year/ Period of Report


End of:
2022
/
Q1
03 Previous Name and Date of Change (If name changed during year)

/
04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

3010 West 69th Street Sioux Falls, SD 57108
05 Name of Contact Person

Elaine A. Rich
06 Title of Contact Person

Assistant Controller
07 Address of Contact Person (Street, City, State, Zip Code)

11 East Park Street, Butte, MT 59701
08 Telephone of Contact Person, Including Area Code

(406) 497-2759
09 This Report is An Original / A Resubmission

(1)
An Original

(2)
A Resubmission
10 Date of Report (Mo, Da, Yr)

03/31/2022
Quarterly Corporate Officer Certification
The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Jeff Berzina
02 Title

Controller
03 Signature

Jeff Berzina
04 Date Signed (Mo, Da, Yr)

05/20/2022
Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
List of Schedules

Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".

Line No.
Title of Schedule
(a)
Reference Page No.
(b)
Remarks
(c)
ScheduleIdentificationAbstract
Identification
1
ScheduleListOfSchedulesAbstract
List of Schedules (Electric Utility)
2
1
ScheduleImportantChangesDuringTheQuarterYearAbstract
Important Changes During the Quarter
108
2
ScheduleComparativeBalanceSheetAbstract
Comparative Balance Sheet
110
3
ScheduleStatementOfIncomeAbstract
Statement of Income for the Quarter
114
4
ScheduleRetainedEarningsAbstract
Statement of Retained Earnings for the Quarter
118
5
ScheduleStatementOfCashFlowsAbstract
Statement of Cash Flows
120
6
ScheduleNotesToFinancialStatementsAbstract
Notes to Financial Statements
122
7
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract
Statement of Accum Comp Income, Comp Income, and Hedging Activities
122a
8
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep
200
9
ScheduleElectricPlantInServiceAndAccumulatedProvisionForDepreciationByFunctionAbstract
Electric Plant In Service and Accum Provision For Depr by Function
208
10
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract
Transmission Service and Generation Interconnection Study Costs
231
11
ScheduleOtherRegulatoryAssetsAbstract
Other Regulatory Assets
232
12
ScheduleOtherRegulatoryLiabilitiesAbstract
Other Regulatory Liabilities
278
13
ScheduleElectricOperatingRevenuesAbstract
Elec Operating Revenues (Individual Schedule Lines 300-301)
300
14
ScheduleRegionalTransmissionServiceRevenuesAbstract
Regional Transmission Service Revenues (Account 457.1)
302
Not Applicable
15
ScheduleElectricProductionOtherPowerTransmissionRegionalExpensesAbstract
Electric Prod, Other Power Supply Exp, Trans and Distrib Exp
324
16
ScheduleElectricCustomerAccountServiceSalesAdministrativeAndGeneralExpensesAbstract
Electric Customer Accts, Service, Sales, Admin and General Expenses
325
17
ScheduleTransmissionOfElectricityForOthersAbstract
Transmission of Electricity for Others
328
18
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract
Transmission of Electricity by ISO/RTOs
331
Not Applicable
19
ScheduleTransmissionOfElectricityByOthersAbstract
Transmission of Electricity by Others
332
20
ScheduleDepreciationDepletionAndAmortizationsAbstract
Deprec, Depl and Amort of Elec Plant (403,403.1,404,and 405) (except Amortization of Acquisition Adjustments)
338
21
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract
Amounts Included in ISO/RTO Settlement Statements
397
22
ScheduleMonthlyPeaksAndOutputAbstract
Monthly Peak Loads and Energy Output
399
23
ScheduleMonthlyTransmissionSystemPeakLoadAbstract
Monthly Transmission System Peak Load
400
24
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract
Monthly ISO/RTO Transmission System Peak Load
400a


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
IMPORTANT CHANGES DURING THE QUARTER/YEAR

Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears.

  1. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact.
  2. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization.
  3. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission.
  4. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization.
  5. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc.
  6. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee.
  7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments.
  8. State the estimated annual effect and nature of any important wage scale changes during the year.
  9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year.
  10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest.
  11. (Reserved.)
  12. If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page.
  13. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period.
  14. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.
1. None
2. None
3. None
4. None
5. None
6. See Note 6, "Financing Activities", FERC Order ES19-36-000 and MPSC Order Number 7691 Docket Number D2019.08.046.
7. None
8. None
9. See Note 8, "Commitments and Contingencies".
10. None
12. None
13. None.
14. NA


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlant
Utility Plant (101-106, 114)
200
7,128,776,067
7,084,086,086
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200
344,195,177
284,729,122
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Enter Total of lines 2 and 3)
7,472,971,244
7,368,815,208
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)
200
2,689,733,593
2,648,396,212
6
UtilityPlantNet
Net Utility Plant (Enter Total of line 4 less 5)
4,783,237,651
4,720,418,996
7
NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication
Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)
202
8
NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly
Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9
NuclearFuelAssembliesInReactorMajorOnly
Nuclear Fuel Assemblies in Reactor (120.3)
10
SpentNuclearFuelMajorOnly
Spent Nuclear Fuel (120.4)
11
NuclearFuelUnderCapitalLeases
Nuclear Fuel Under Capital Leases (120.6)
12
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies
(Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)
202
13
NuclearFuelNet
Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14
UtilityPlantAndNuclearFuelNet
Net Utility Plant (Enter Total of lines 6 and 13)
4,783,237,651
4,720,418,996
15
OtherElectricPlantAdjustments
Utility Plant Adjustments (116)
357,585,527
357,585,527
16
GasStoredUndergroundNoncurrent
Gas Stored Underground - Noncurrent (117)
36,198,708
36,190,017
17
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
18
NonutilityProperty
Nonutility Property (121)
686,805
686,805
19
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Prov. for Depr. and Amort. (122)
29,270
29,270
20
InvestmentInAssociatedCompanies
Investments in Associated Companies (123)
21
InvestmentInSubsidiaryCompanies
Investment in Subsidiary Companies (123.1)
224
24,788,653
24,377,535
23
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
228
24
OtherInvestments
Other Investments (124)
20,986,811
18,262,019
25
SinkingFunds
Sinking Funds (125)
26
DepreciationFund
Depreciation Fund (126)
27
AmortizationFundFederal
Amortization Fund - Federal (127)
28
OtherSpecialFunds
Other Special Funds (128)
29
SpecialFunds
Special Funds (Non Major Only) (129)
30
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
31
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
32
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Lines 18-21 and 23-31)
46,432,999
43,297,089
33
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
34
CashAndWorkingFunds
Cash and Working Funds (Non-major Only) (130)
35
Cash
Cash (131)
12,781,756
2,300,750
36
SpecialDeposits
Special Deposits (132-134)
16,007,027
14,658,170
37
WorkingFunds
Working Fund (135)
23,250
23,250
38
TemporaryCashInvestments
Temporary Cash Investments (136)
39
NotesReceivable
Notes Receivable (141)
40
CustomerAccountsReceivable
Customer Accounts Receivable (142)
90,507,613
86,846,850
41
OtherAccountsReceivable
Other Accounts Receivable (143)
7,452,412
8,867,792
42
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
2,657,668
2,319,115
43
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
44
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Assoc. Companies (146)
3,159,014
2,818,214
45
FuelStock
Fuel Stock (151)
227
7,425,703
7,509,623
46
FuelStockExpensesUndistributed
Fuel Stock Expenses Undistributed (152)
227
47
Residuals
Residuals (Elec) and Extracted Products (153)
227
48
PlantMaterialsAndOperatingSupplies
Plant Materials and Operating Supplies (154)
227
61,267,389
53,538,725
49
Merchandise
Merchandise (155)
227
50
OtherMaterialsAndSupplies
Other Materials and Supplies (156)
227
51
NuclearMaterialsHeldForSale
Nuclear Materials Held for Sale (157)
202/227
52
AllowanceInventoryAndWithheld
Allowances (158.1 and 158.2)
228
53
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
228
54
StoresExpenseUndistributed
Stores Expense Undistributed (163)
227
489,252
55
GasStoredCurrent
Gas Stored Underground - Current (164.1)
1,169,377
18,828,613
56
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57
Prepayments
Prepayments (165)
(a)
18,914,429
22,690,392
58
AdvancesForGas
Advances for Gas (166-167)
59
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
60
RentsReceivable
Rents Receivable (172)
317,862
54,488
61
AccruedUtilityRevenues
Accrued Utility Revenues (173)
78,388,840
98,149,252
62
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
524,301
258,105
63
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
64
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
65
DerivativeInstrumentAssetsHedges
Derivative Instrument Assets - Hedges (176)
66
DerivativeInstrumentAssetsHedgesLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67
CurrentAndAccruedAssets
Total Current and Accrued Assets (Lines 34 through 66)
294,792,053
314,225,109
68
DeferredDebitsAbstract
DEFERRED DEBITS
69
UnamortizedDebtExpense
Unamortized Debt Expenses (181)
10,081,164
11,120,970
70
ExtraordinaryPropertyLosses
Extraordinary Property Losses (182.1)
230a
71
UnrecoveredPlantAndRegulatoryStudyCosts
Unrecovered Plant and Regulatory Study Costs (182.2)
230b
72
OtherRegulatoryAssets
Other Regulatory Assets (182.3)
232
695,106,790
685,148,784
73
PreliminarySurveyAndInvestigationCharges
Prelim. Survey and Investigation Charges (Electric) (183)
74
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges
Preliminary Natural Gas Survey and Investigation Charges 183.1)
75
OtherPreliminarySurveyAndInvestigationCharges
Other Preliminary Survey and Investigation Charges (183.2)
76
ClearingAccounts
Clearing Accounts (184)
1,621,307
4,169
77
TemporaryFacilities
Temporary Facilities (185)
78
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
8,976,695
8,602,501
79
DeferredLossesFromDispositionOfUtilityPlant
Def. Losses from Disposition of Utility Plt. (187)
80
ResearchDevelopmentAndDemonstrationExpenditures
Research, Devel. and Demonstration Expend. (188)
352
81
UnamortizedLossOnReacquiredDebt
Unamortized Loss on Reaquired Debt (189)
(b)
24,905,833
25,635,857
82
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234
155,192,902
160,914,104
83
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
78,161,494
94,663,379
84
DeferredDebits
Total Deferred Debits (lines 69 through 83)
974,046,185
986,089,764
85
AssetsAndOtherDebits
TOTAL ASSETS (lines 14-16, 32, 67, and 84)
6,492,293,123
6,457,806,502


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
FOOTNOTE DATA

(a) Concept: Prepayments
South Dakota Operations Prepayments (165) are $10,836,540 and $14,201,612 for 2022 and 2021, respectively.

Montana Operations Prepayments (165) are $8,077,889 and $8,488,780 for 2022 and 2021, respectively.
(b) Concept: UnamortizedLossOnReacquiredDebt
Montana Operations Unamortized Loss on Reacquired Debt (189) is $22,010,442 and $22,530,850 for 2022 and 2021, respectively.

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
ProprietaryCapitalAbstract
PROPRIETARY CAPITAL
2
CommonStockIssued
Common Stock Issued (201)
250
576,921
576,063
3
PreferredStockIssued
Preferred Stock Issued (204)
250
4
CapitalStockSubscribed
Capital Stock Subscribed (202, 205)
5
StockLiabilityForConversion
Stock Liability for Conversion (203, 206)
6
PremiumOnCapitalStock
Premium on Capital Stock (207)
7
OtherPaidInCapital
Other Paid-In Capital (208-211)
253
1,719,069,992
1,716,226,995
8
InstallmentsReceivedOnCapitalStock
Installments Received on Capital Stock (212)
252
9
DiscountOnCapitalStock
(Less) Discount on Capital Stock (213)
254
10
CapitalStockExpense
(Less) Capital Stock Expense (214)
254b
11
RetainedEarnings
Retained Earnings (215, 215.1, 216)
118
751,251,658
725,880,305
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118
283,630
446,074
13
ReacquiredCapitalStock
(Less) Reaquired Capital Stock (217)
250
98,986,481
98,248,245
14
NoncorporateProprietorship
Noncorporate Proprietorship (Non-major only) (218)
15
AccumulatedOtherComprehensiveIncome
Accumulated Other Comprehensive Income (219)
122(a)(b)
5,213,833
5,167,596
16
ProprietaryCapital
Total Proprietary Capital (lines 2 through 15)
2,366,981,887
2,339,713,596
17
LongTermDebtAbstract
LONG-TERM DEBT
18
Bonds
Bonds (221)
256
2,179,660,000
2,179,660,000
19
ReacquiredBonds
(Less) Reaquired Bonds (222)
256
20
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256
21
OtherLongTermDebt
Other Long-Term Debt (224)
256
340,000,000
373,000,000
22
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
23
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Debit (226)
54,306
61,389
24
LongTermDebt
Total Long-Term Debt (lines 18 through 23)
2,519,605,694
2,552,598,611
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases - Noncurrent (227)
11,908,983
12,829,411
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
(a)
5,946,933
7,061,829
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
(b)
5,830,961
6,434,213
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
83,676,026
88,530,057
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
34
AssetRetirementObligations
Asset Retirement Obligations (230)
40,549,547
40,747,410
35
OtherNoncurrentLiabilities
Total Other Noncurrent Liabilities (lines 26 through 34)
147,912,450
155,602,920
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
NotesPayable
Notes Payable (231)
92,403
38
AccountsPayable
Accounts Payable (232)
106,878,334
120,452,816
39
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
40
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
3,985,035
3,931,236
41
CustomerDeposits
Customer Deposits (235)
10,468,315
8,573,478
42
TaxesAccrued
Taxes Accrued (236)
262
131,950,241
79,488,912
43
InterestAccrued
Interest Accrued (237)
26,063,514
18,567,598
44
DividendsDeclared
Dividends Declared (238)
45
MaturedLongTermDebt
Matured Long-Term Debt (239)
46
MaturedInterest
Matured Interest (240)
47
TaxCollectionsPayable
Tax Collections Payable (241)
2,599,493
2,178,547
48
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
(c)
55,211,656
63,691,637
49
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
3,899,770
4,012,828
50
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
51
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
52
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
53
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54
CurrentAndAccruedLiabilities
Total Current and Accrued Liabilities (lines 37 through 53)
341,148,761
300,897,052
55
DeferredCreditsAbstract
DEFERRED CREDITS
56
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
(d)
85,784,671
80,779,904
57
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
266
474,392
517,968
58
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
59
OtherDeferredCredits
Other Deferred Credits (253)
269
174,280,562
173,125,630
60
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
183,506,380
185,656,769
61
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reaquired Debt (257)
62
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accum. Deferred Income Taxes-Accel. Amort.(281)
272
63
AccumulatedDeferredIncomeTaxesOtherProperty
Accum. Deferred Income Taxes-Other Property (282)
435,099,565
431,345,154
64
AccumulatedDeferredIncomeTaxesOther
Accum. Deferred Income Taxes-Other (283)
237,498,761
237,568,898
65
DeferredCredits
Total Deferred Credits (lines 56 through 64)
1,116,644,331
1,108,994,323
66
LiabilitiesAndOtherCredits
TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)
6,492,293,123
6,457,806,502


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
FOOTNOTE DATA

(a) Concept: AccumulatedProvisionForInjuriesAndDamages
South Dakota Operations Provision for Injuries and Damages (228.2) are $654,020 and $570,311 for 2022 and 2021, respectively.

Montana Operations Provision for Injuries and Damages (228.2) are $5,292,913 and $6,491,517 for 2022 and 2021, respectively.
(b) Concept: AccumulatedProvisionForPensionsAndBenefits
Montana Operations Accumulated Provision for Pensions and Benefits (228.3) are $2,807,964 and $3,478,599 for 2022 and 2021, respectively.
(c) Concept: MiscellaneousCurrentAndAccruedLiabilities
Montana Operations Miscellaneous Current and Accrued Liabilities (242) are $43,603,983 and $46,613,454 for 2022 and 2021, respectively.
(d) Concept: CustomerAdvancesForConstruction
Montana Operations Customer Advances for Construction (252) are $85,784,671 and $80,779,904 for 2022 and 2021, respectively.

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
STATEMENT OF INCOME

Quarterly

  1. Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only.
  2. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year.
  3. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter.
  4. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter.
  5. If additional columns are needed, place them in a footnote.

Annual or Quarterly if applicable

  1. Do not report fourth quarter data in columns (e) and (f)
  2. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals.
  3. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above.
  4. Use page 122 for important notes regarding the statement of income for any account thereof.
  5. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases.
  6. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts.
  7. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122.
  8. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes.
  9. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports.
  10. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.
Title of Account
(a)
(Ref.) Page No.
(b)
Total Current Year to Date Balance for Quarter/Year
(c)
Total Prior Year to Date Balance for Quarter/Year
(d)
Current 3 Months Ended - Quarterly Only - No 4th Quarter
(e)
Prior 3 Months Ended - Quarterly Only - No 4th Quarter
(f)
Electric Utility Current Year to Date (in dollars)
(g)
Electric Utility Previous Year to Date (in dollars)
(h)
Gas Utiity Current Year to Date (in dollars)
(i)
Gas Utility Previous Year to Date (in dollars)
(j)
Other Utility Current Year to Date (in dollars)
(k)
Other Utility Previous Year to Date (in dollars)
(l)
1
UtilityOperatingIncomeAbstract
UTILITY OPERATING INCOME
2
OperatingRevenues
Operating Revenues (400)
300
425,510,675
375,644,946
425,510,675
375,644,946
276,313,581
265,416,902
148,815,542
109,930,800
381,552
297,244
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
320
229,218,591
175,621,610
229,218,591
175,621,610
131,745,226
118,754,585
97,186,465
56,650,204
286,900
216,821
5
MaintenanceExpense
Maintenance Expenses (402)
320
13,137,088
11,997,109
13,137,088
11,997,109
10,906,663
10,248,713
2,229,258
1,748,332
1,167
64
6
DepreciationExpense
Depreciation Expense (403)
336
41,998,747
40,010,584
41,998,747
40,010,584
34,823,251
33,111,150
7,165,320
6,889,258
10,176
10,176
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336
3,170,924
3,079,925
3,170,924
3,079,925
1,765,747
1,585,467
1,405,176
1,494,458
9
AmortizationOfElectricPlantAcquisitionAdjustments
Amort. of Utility Plant Acq. Adj. (406)
336
3,775,443
3,775,443
3,775,443
3,775,443
3,987,069
3,987,069
211,626
211,626
10
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts
Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11
AmortizationOfConversionExpenses
Amort. of Conversion Expenses (407.2)
12
RegulatoryDebits
Regulatory Debits (407.3)
7,015,216
8,979,554
7,015,216
8,979,554
1,721,138
3,795,459
5,294,078
5,184,095
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
2,130,691
3,095,234
2,130,691
3,095,234
1,808,306
2,775,336
322,385
319,898
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262
48,745,819
49,930,386
48,745,819
49,930,386
37,830,253
38,799,224
10,899,155
11,115,123
16,410
16,039
15
IncomeTaxesOperatingIncome
Income Taxes - Federal (409.1)
262
12,717,373
683,667
12,717,373
683,667
4,443,720
2,848,803
8,258,744
2,153,720
14,909
11,416
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes - Other (409.1)
262
5,284,107
3,390,998
5,284,107
3,390,998
2,648,758
1,585,510
2,630,210
1,801,553
5,139
3,935
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision for Deferred Income Taxes (410.1)
234, 272
12,189,543
25,755,109
12,189,543
25,755,109
9,936,102
17,440,325
2,255,876
8,315,958
2,435
1,174
18
ProvisionForDeferredIncomeTaxesCreditOperatingIncome
(Less) Provision for Deferred Income Taxes-Cr. (411.1)
234, 272
31,721,940
29,703,852
31,721,940
29,703,852
21,938,618
21,396,288
9,783,323
8,307,564
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adj. - Net (411.4)
266
43,576
90
43,576
90
43,576
90
20
GainsFromDispositionOfPlant
(Less) Gains from Disp. of Utility Plant (411.6)
21
LossesFromDispositionOfServiceCompanyPlant
Losses from Disp. of Utility Plant (411.7)
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
2,680
2,680
2,680
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
24
AccretionExpense
Accretion Expense (411.10)
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)
343,356,644
289,060,555
343,356,644
289,060,555
216,017,427
202,289,665
127,006,948
86,513,613
332,266
257,277
27
NetUtilityOperatingIncome
Net Util Oper Inc (Enter Tot line 2 less 25)
82,154,031
86,584,391
82,154,031
86,584,391
60,296,154
63,127,237
21,808,594
23,417,187
49,286
39,967
28
OtherIncomeAndDeductionsAbstract
Other Income and Deductions
29
OtherIncomeAbstract
Other Income
30
NonutilityOperatingIncomeAbstract
Nonutilty Operating Income
31
RevenuesFromMerchandisingJobbingAndContractWork
Revenues From Merchandising, Jobbing and Contract Work (415)
103,207
139,205
103,207
139,205
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
38,773
22,669
38,773
22,669
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
91,414
404
91,414
404
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
200,957
172,794
200,957
172,794
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
162,444
315,489
162,444
315,489
37
InterestAndDividendIncome
Interest and Dividend Income (419)
742,664
816
742,664
816
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
3,116,490
1,981,729
3,116,490
1,981,729
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
190,890
1,766,254
190,890
1,766,254
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
41
OtherIncome
TOTAL Other Income (Enter Total of lines 31 thru 40)
3,842,491
3,377,456
3,842,491
3,377,456
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
45
Donations
Donations (426.1)
334,142
275,945
334,142
275,945
46
LifeInsurance
Life Insurance (426.2)
47
Penalties
Penalties (426.3)
92,000
92,000
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Exp. for Certain Civic, Political & Related Activities (426.4)
112,320
84,008
112,320
84,008
49
OtherDeductions
Other Deductions (426.5)
220,438
1,878,739
220,438
1,878,739
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
666,900
2,146,692
666,900
2,146,692
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262
699
11,736
699
11,736
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262
10,475,927
744,049
10,475,927
744,049
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262
27,739
766,443
27,739
766,443
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Inc. Taxes (410.2)
234, 272
13,614,744
6,207,648
13,614,744
6,207,648
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Cr. (411.2)
234, 272
596,777
4,964,519
596,777
4,964,519
57
InvestmentTaxCreditAdjustmentsNonutilityOperations
Investment Tax Credit Adj.-Net (411.5)
58
InvestmentTaxCredits
(Less) Investment Tax Credits (420)
59
TaxesOnOtherIncomeAndDeductions
TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)
2,515,000
1,232,471
2,515,000
1,232,471
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
660,591
1,707
660,591
1,707
61
InterestChargesAbstract
Interest Charges
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
22,159,342
21,902,151
22,159,342
21,902,151
63
AmortizationOfDebtDiscountAndExpense
Amort. of Debt Disc. and Expense (428)
301,225
446,374
301,225
446,374
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reaquired Debt (428.1)
702,482
702,482
702,482
702,482
65
AmortizationOfPremiumOnDebtCredit
(Less) Amort. of Premium on Debt-Credit (429)
66
AmortizationOfGainOnReacquiredDebtCredit
(Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67
InterestOnDebtToAssociatedCompanies
Interest on Debt to Assoc. Companies (430)
68
OtherInterestExpense
Other Interest Expense (431)
1,773,688
1,325,521
1,773,688
1,325,521
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)
1,231,950
864,924
1,231,950
864,924
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
23,704,787
23,511,604
23,704,787
23,511,604
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
59,109,835
63,071,080
59,109,835
63,071,080
72
ExtraordinaryItemsAbstract
Extraordinary Items
73
ExtraordinaryIncome
Extraordinary Income (434)
74
ExtraordinaryDeductions
(Less) Extraordinary Deductions (435)
75
NetExtraordinaryItems
Net Extraordinary Items (Total of line 73 less line 74)
76
IncomeTaxesExtraordinaryItems
Income Taxes-Federal and Other (409.3)
262
77
ExtraordinaryItemsAfterTaxes
Extraordinary Items After Taxes (line 75 less line 76)
78
NetIncomeLoss
Net Income (Total of line 71 and 77)
59,109,835
63,071,080
59,109,835
63,071,080


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report


End of:
2022
/
Q1
STATEMENT OF RETAINED EARNINGS
  1. Do not report Lines 49-53 on the quarterly report.
  2. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year.
  3. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b).
  4. State the purpose and amount for each reservation or appropriation of retained earnings.
  5. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order.
  6. Show dividends for each class and series of capital stock.
  7. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings.
  8. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated.
  9. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.
Item
(a)
Contra Primary Account Affected
(b)
Current Quarter/Year Year to Date Balance
(c)
Previous Quarter/Year Year to Date Balance
(d)
UnappropriatedRetainedEarningsAbstract
UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1
UnappropriatedRetainedEarnings
Balance-Beginning of Period
725,880,305
666,673,846
2
ChangesAbstract
Changes
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
4
AdjustmentsToRetainedEarningsCreditAbstract
Adjustments to Retained Earnings Credit
9
AdjustmentsToRetainedEarningsCredit
TOTAL Credits to Retained Earnings (Acct. 439)
10
AdjustmentsToRetainedEarningsDebitAbstract
Adjustments to Retained Earnings Debit
15
AdjustmentsToRetainedEarningsDebit
TOTAL Debits to Retained Earnings (Acct. 439)
16
BalanceTransferredFromIncome
Balance Transferred from Income (Account 433 less Account 418.1)
59,272,279
187,689,061
17
AppropriationsOfRetainedEarningsAbstract
Appropriations of Retained Earnings (Acct. 436)
22
AppropriationsOfRetainedEarnings
TOTAL Appropriations of Retained Earnings (Acct. 436)
23
DividendsDeclaredPreferredStockAbstract
Dividends Declared-Preferred Stock (Account 437)
29
DividendsDeclaredPreferredStock
TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30
DividendsDeclaredCommonStockAbstract
Dividends Declared-Common Stock (Account 438)
30.1
DividendsDeclaredCommonStock
Common Stock Dividend
33,900,926
128,482,602
36
DividendsDeclaredCommonStock
TOTAL Dividends Declared-Common Stock (Acct. 438)
33,900,926
128,482,602
37
TransfersFromUnappropriatedUndistributedSubsidiaryEarnings
Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
38
UnappropriatedRetainedEarnings
Balance - End of Period (Total 1,9,15,16,22,29,36,37)
751,251,658
725,880,305
39
AppropriatedRetainedEarningsAbstract
APPROPRIATED RETAINED EARNINGS (Account 215)
45
AppropriatedRetainedEarnings
TOTAL Appropriated Retained Earnings (Account 215)
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract
APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46
AppropriatedRetainedEarningsAmortizationReserveFederal
TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47
AppropriatedRetainedEarningsIncludingReserveAmortization
TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48
RetainedEarnings
TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)
751,251,658
725,880,305
UnappropriatedUndistributedSubsidiaryEarningsAbstract
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49
UnappropriatedUndistributedSubsidiaryEarnings
Balance-Beginning of Year (Debit or Credit)
50
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings for Year (Credit) (Account 418.1)
51
DividendsReceived
(Less) Dividends Received (Debit)
52
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53
UnappropriatedUndistributedSubsidiaryEarnings
Balance-End of Year (Total lines 49 thru 52)


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
STATEMENT OF CASH FLOWS
  1. Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc.
  2. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet.
  3. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid.
  4. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.
Description (See Instructions No.1 for explanation of codes)
(a)
Current Year to Date Quarter/Year
(b)
Previous Year to Date Quarter/Year
(c)
1
NetCashFlowFromOperatingActivitiesAbstract
Net Cash Flow from Operating Activities
2
NetIncomeLoss
Net Income (Line 78(c) on page 117)
59,109,835
63,071,080
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
41,998,747
40,010,584
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of
6,946,367
6,855,368
5.2
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other Noncash Charges to Income, Net
(a)
5,122,256
(f)
4,526,671
8
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
6,514,430
2,705,614
9
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustment (Net)
43,576
90
10
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
2,247,630
190,079
11
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
10,503,744
4,183,092
12
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
13
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
52,150,046
31,986,131
14
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
6,421,947
21,254,943
15
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
2,150,389
4,604,315
16
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
3,116,490
1,981,729
17
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
162,444
315,488
18
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other (provide details in footnote):
18.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other
(b)
27,500,502
(g)
55,023,736
22
NetCashFlowFromOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)
195,843,373
65,568,066
24
CashFlowsFromInvestmentActivitiesAbstract
Cash Flows from Investment Activities:
25
ConstructionAndAcquisitionOfPlantIncludingLandAbstract
Construction and Acquisition of Plant (including land):
26
GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Gross Additions to Utility Plant (less nuclear fuel)
98,922,847
76,991,653
27
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
28
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
20,179,426
3,403,982
29
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
30
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
3,116,490
1,981,729
31
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other (provide details in footnote):
34
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 26 thru 33)
115,985,783
78,413,906
36
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
37
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
39
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Investments in and Advances to Assoc. and Subsidiary Companies
40
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies
Contributions and Advances from Assoc. and Subsidiary Companies
41
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract
Disposition of Investments in (and Advances to)
42
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44
PurchaseOfInvestmentSecurities
Purchase of Investment Securities (a)
45
ProceedsFromSalesOfInvestmentSecurities
Proceeds from Sales of Investment Securities (a)
46
LoansMadeOrPurchased
Loans Made or Purchased
47
CollectionsOnLoans
Collections on Loans
49
NetIncreaseDecreaseInReceivablesInvestingActivities
Net (Increase) Decrease in Receivables
50
NetIncreaseDecreaseInInventoryInvestingActivities
Net (Increase) Decrease in Inventory
51
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities
Net (Increase) Decrease in Allowances Held for Speculation
52
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
53
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other (provide details in footnote):
53.1
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Investment in Equity Securities
567,360
57
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)
116,553,143
78,413,906
59
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
60
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
61
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Long-Term Debt (b)
99,915,000
62
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Preferred Stock
63
ProceedsFromIssuanceOfCommonStockFinancingActivities
Common Stock
97,030
64
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other (provide details in footnote):
64.1
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription
Treasury Stock Activity
554,814
299,895
66
NetIncreaseInShortTermDebt
Net Increase in Short-Term Debt (c)
67
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
67.1
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other
(c)
92,403
67.2
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Line of Credit (Repayments) Borrowings, Net
70
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total 61 thru 69)
559,441
99,615,105
72
PaymentsForRetirementAbstract
Payments for Retirement of:
73
PaymentsForRetirementOfLongTermDebtFinancingActivities
Long-term Debt (b)
74
PaymentsForRetirementOfPreferredStockFinancingActivities
Preferred Stock
75
PaymentsForRetirementOfCommonStockFinancingActivities
Common Stock
76
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Debt Financing Costs
441,705
76.2
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Line of Credit (Repayments) Borrowings, Net
33,000,000
49,000,000
78
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
100,000,000
80
DividendsOnPreferredStock
Dividends on Preferred Stock
81
DividendsOnCommonStock
Dividends on Common Stock
33,900,926
31,125,505
83
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)
67,460,367
17,047,895
85
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract
Net Increase (Decrease) in Cash and Cash Equivalents
86
NetIncreaseDecreaseInCashAndCashEquivalents
Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)
11,829,863
4,202,055
88
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
(d)
16,982,170
(h)
15,397,446
90
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
(e)
28,812,033
(i)
19,599,501


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
FOOTNOTE DATA

(a) Concept: NoncashAdjustmentsToCashFlowsFromOperatingActivities
3/31/2022 3/31/2021
Other Noncash Charges to Income, Net:
Amortization of debt issue costs, discount, and deferred hedge gain 1,926,400  1,302,292 
Other noncash gains 438,391  1,110 
Stock based compensation costs 2,757,465  3,223,269 
5,122,256  4,526,671 
Other Assets and Liabilities, Net:
Net change - other current assets 3,246,393  82,606 
Net change - accrued utility revenues 19,760,412  5,147,108 
Net change - deferred debits 14,514,500  (48,132,526)
Net change - deferred credits (2,572,943) 2,935,091 
Net change - noncurrent liabilities (7,447,861) (15,056,015)
27,500,501  (55,023,736)
(b) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
Refer to footnote (a) for details.
(c) Concept: OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Increase in Notes payable (231)
(d) Concept: CashAndCashEquivalents
3/31/2022 12/31/2021 3/31/2021 12/31/2020
Cash (131) 12,781,764  2,300,750  7,971,922  5,454,203 
Working Funds (135) 23,250  23,250  22,950  22,950 
Special Funds (125-128) —  —  250,000  250,000 
Other Special Deposits (134) 16,007,027  14,658,170  11,354,629  9,670,293 
Total 28,812,041  16,982,170  19,599,501  15,397,446 
(e) Concept: CashAndCashEquivalents
Refer to footnote (d) for details.
(f) Concept: NoncashAdjustmentsToCashFlowsFromOperatingActivities
Refer to footnote (a) for details.
(g) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
Refer to footnote (a) for details.
(h) Concept: CashAndCashEquivalents
Refer to footnote (d) for details.
(i) Concept: CashAndCashEquivalents
Refer to footnote (d) for details.

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
NOTES TO FINANCIAL STATEMENTS
  1. Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
  2. Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
  3. For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Cormmission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
  4. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
  5. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
  6. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
  7. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
  8. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
  9. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.
(1) Nature of Operations and Basis of Consolidation

NorthWestern Corporation, doing business as NorthWestern Energy, provides electricity and/or natural gas to approximately 753,600 customers in Montana, South Dakota, Nebraska and Yellowstone National Park.

The preparation of financial statements in conformity with accounting requirements of the Federal Energy Regulatory Commission (FERC) as set forth in its applicable Uniform System of Accounts requires us to make estimates and assumptions that may affect the reported amounts of assets, liabilities, revenues and expenses during the reporting period. Actual results could differ from those estimates. The unaudited Financial Statements reflect all adjustments (which unless otherwise noted are normal and recurring in nature) that are, in our opinion, necessary to fairly present our financial position, results of operations and cash flows. The actual results for the interim periods are not necessarily indicative of the operating results to be expected for a full year or for other interim periods. Events occurring subsequent to March 31, 2022 have been evaluated as to their potential impact to the Financial Statements through the date of issuance.

The Financial Statements included herein have been prepared by NorthWestern, without audit, pursuant to the rules and regulations of the FERC as set forth in its applicable Uniform System of Accounts. Certain information and footnote disclosures normally included in financial statements prepared in accordance with the accounting requirements of the FERC as set forth in its applicable Uniform System of Accounts and published accounting releases have been condensed or omitted pursuant to such rules and regulations; however, we believe that the condensed disclosures provided are adequate to make the information presented not misleading. We recommend that these Financial Statements be read in conjunction with the audited financial statements and related footnotes included in our Annual FERC Form 1 Report for the year ended December 31, 2021.

Financial Statement Presentation

The financial statements are presented on the basis of the accounting requirements of the FERC as set forth in its applicable Uniform System of Accounts and published accounting releases, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America (GAAP). This report differs from GAAP due to FERC requiring the presentation of subsidiaries on the equity method of accounting, which differs from Accounting Standards Codification (ASC) 810, Consolidation. ASC 810 requires that all majority-owned subsidiaries be consolidated (see Note 4). The other significant differences consist of the following:

Earnings per share and footnotes for revenue from contracts with customers, and segment and related information, are not presented;
Removal and decommissioning costs of generation, transmission and distribution assets are reflected in the Balance Sheets as a component of accumulated depreciation of $486.2 million and $479.3 million as of March 31,2022 and December 31, 2021, respectively, in accordance with regulatory treatment as compared to regulatory liabilities for GAAP purposes;
Goodwill is reflected in the Balance Sheets as a utility plant adjustments of $357.6 million as of March 31,2022 and December 31, 2021, respectively, in accordance with regulatory treatment, as compared to goodwill for GAAP purposes;
The write-down of plant values associated with the 2002 acquisition of the Montana operations is reflected in the Balance Sheets as a component of accumulated depreciation of $147.6 million for March 31,2022 and December 31, 2021, respectively, in accordance with regulatory treatment as compared to plant for GAAP purposes;
The current portion of gas stored underground is reflected in the Balance Sheets as current and accrued assets, as compared to inventory for GAAP purposes;
Operating lease right of use assets are classified in the Balance Sheets as capital leases in accordance with regulatory treatment, as compared to non-current assets for GAAP purposes;
Operating lease liabilities are reflected as current and long term obligations under capital leases in the Balance Sheets, as compared to accrued expenses and long term liabilities for GAAP purposes;
Unamortized debt expense is classified in the Balance Sheets as deferred debits in accordance with regulatory treatment, as compared to long-term debt for GAAP purposes;
Current and long-term debt is classified in the Balance Sheets as all long-term debt in accordance with regulatory treatment, while current and long-term debt are presented separately for GAAP reporting;
The current portion of the provision for injuries and damages and the expected insurance proceeds receivable related to the provision for injuries and damages are reported as a current liability for GAAP purposes, as compared to a non-current liability for FERC purposes;
Accumulated deferred tax assets and liabilities are classified in the Balance Sheets as gross non-current deferred debits and credits, respectively, while GAAP presentation reflects a net non-current deferred tax liability;
Stranded tax effects associated with the Tax Cuts and Jobs Act are included in accumulated other comprehensive income (AOCI) in accordance with regulatory treatment, while included in retained earnings for GAAP purposes;
Uncertain tax positions related to temporary differences are classified in the Balance Sheets within the deferred tax accounts in accordance with regulatory treatment, as compared to other noncurrent liabilities for GAAP purposes. In addition, interest related to uncertain tax positions is recognized in interest expense in accordance with regulatory treatment, as compared to income tax expense for GAAP purposes;
Net periodic benefit costs and net periodic postretirement benefit costs are reflected in operating expense for FERC purposes, as compared to the GAAP presentation, which reflects the current service costs component of the net periodic benefit costs in operating expenses and the other components outside of income from operations. In addition, only the service cost component of net periodic benefit cost is eligible for capitalization for GAAP purposes, as compared to the total net periodic benefit costs for FERC purposes;
Regulatory assets and liabilities are reflected in the Balance Sheets as non-current items, while current and non-current amounts are presented separately for GAAP;
Unbilled revenue is reflected in the Balance Sheets as Accrued utility revenue in accordance with regulatory treatment, as compared to Accounts receivable, net for GAAP purposes;
Implementation costs associated with cloud computing arrangements are reflected on the Balance Sheets as Miscellaneous Intangible Plant in accordance with regulatory treatment, as compared to Other current assets for GAAP purposes. Additionally, these cash outflows are presented within investing activities cash outflows in the Statement of Cash Flows in accordance with regulatory treatment, as compared to operating activities cash outflows for GAAP purposes; and
GAAP revenue differs from FERC revenue primarily due to the equity method of accounting as discussed above, netting of electric purchases and sales for resale in revenue for the GAAP presentation as compared to a gross presentation for FERC purposes (with the exception of those transactions in a regional transmission organization (RTO)), the netting of RTO transmission transactions for the GAAP presentation as compared to a gross presentation for FERC purposes, and the classification of regulatory amortizations in revenue for GAAP purposes as compared to expense for FERC purposes.

The following table reconciles GAAP revenues to FERC revenues by segment for the three months ended 2022 and 2021 (in millions):
Three Months Ended March 31,2022
TotalElectricNatural GasOther
GAAP Revenues$394.5 $271.7 $122.8 $— 
Revenue from equity investments(0.7)— (0.7)— 
Grossing revenues / power purchases11.4 11.4 — — 
Regulatory amortizations21.5 (5.7)27.2 — 
Other(1.2)(1.1)(0.5)0.4 
FERC Revenues$425.5 $276.3 $148.8 $0.4 

Three Months Ended March 31,2021
TotalElectricNatural GasOther
GAAP Revenues$400.8 $270.1 $130.7 $— 
Revenue from equity investments(0.7)— (0.7)— 
Grossing revenues / power purchases8.3 8.3 — — 
Regulatory amortizations(33.7)(13.9)(19.8)— 
Other0.9 0.9 (0.3)0.3 
FERC Revenues$375.6 $265.4 $109.9 $0.3 

Supplemental Cash Flow Information

The following table provides a reconciliation of cash, workings funds, other special funds, and special deposits reported within the Balance Sheets that sum to the total of the same such amounts shown in the Statements of Cash Flows (in thousands):

March 31,2022December 31, 2021March 31,2021December 31, 2020
Cash$12,782 $2,301 $7,972 $5,454 
Working funds23 23 23 23 
Other special funds— — 250 250 
Special deposits16,007 14,658 11,355 9,670 
Total shown in the Statements of Cash Flows$28,812 $16,982 $19,600 $15,397 

Utility Plant Adjustment

We completed our annual utility plant adjustment impairment test as of April 1, 2021 and no impairment was identified. We calculate the fair value of our reporting units by considering various factors, including valuation studies based primarily on a discounted cash flow analysis, with published industry valuations and market data as supporting information. Key assumptions in the determination of fair value include the use of an appropriate discount rate and estimated future cash flows. In estimating cash flows, we incorporate expected long-term growth rates in our service territory, regulatory stability, and commodity prices (where appropriate), as well as other factors that affect our revenue, expense and capital expenditure projections.
(2) Regulatory Matters

FERC Financial Audit

We are subject to FERC’s jurisdiction and regulations with respect to rates for electric transmission service in interstate commerce and electricity sold at wholesale rates, the issuance of certain securities, and incurrence of certain long-term debt, among other things. The Division of Audits and Accounting in the Office of Enforcement of FERC initiated a routine audit of NorthWestern Corporation for the period of January 1, 2018 to the present to evaluate our compliance with FERC accounting and financial reporting requirements. We responded to several sets of data requests as part of the audit process and in April 2022 received a draft audit report from FERC. Based on review of the draft report, we believe final resolution of the identified audit findings and recommendations will not have a material financial impact on us.
(3) Income Taxes

We compute income tax expense for each quarter based on the estimated annual effective tax rate for the year, adjusted for certain discrete items. Our effective tax rate typically differs from the federal statutory tax rate due to the regulatory impact of flowing through the federal and state tax benefit of repairs deductions, state tax benefit of accelerated tax depreciation deductions (including bonus depreciation when applicable) and production tax credits. The regulatory accounting treatment of these deductions requires immediate income recognition for temporary tax differences of this type, which is referred to as the flow-through method. When the flow-through method of accounting for temporary differences is reflected in regulated revenues, we record deferred income taxes and establish related regulatory assets and liabilities.

The following table summarizes the differences between our effective tax rate and the federal statutory rate (in thousands):

Three Months Ended March 31,
20222021
Income Before Income Taxes$60,050 $63,050 
Income tax calculated at federal statutory rate12,610 21.0 %13,241 21.0 %
Permanent or flow-through adjustments:
State income tax, net of federal provisions400 0.7 55 0.1 
Flow-through repairs deductions(6,801)(11.3)(7,853)(12.5)
Production tax credits(3,824)(6.5)(4,307)(6.8)
Share-based compensation(411)(0.7)(261)(0.4)
Amortization of excess deferred income tax(255)(0.4)(265)(0.4)
Plant and depreciation of flow-through items(253)(0.4)(340)(0.5)
Other, net(526)(0.9)(291)(0.5)
(11,670)(19.5)(13,262)(21.0)
Income tax expense (benefit)940 1.5 (21)0.0 

Uncertain Tax Positions
We recognize tax positions that meet the more-likely-than-not threshold as the largest amount of tax benefit that is greater than 50 percent likely of being realized upon ultimate settlement with a taxing authority that has full knowledge of all relevant information. We had unrecognized tax benefits of approximately $31.6 million as of March 31, 2022, including approximately $28.1 million that, if recognized, would impact our effective tax rate. We do not anticipate that total unrecognized tax benefits will significantly change due to the settlement of audits or the expiration of statutes of limitation within the next twelve months.

Our policy is to recognize interest related to uncertain tax positions in income tax expense. As of March 31, 2022, we have accrued $0.7 million for the payment of interest on the Balance Sheets. As of December 31, 2021, we had accrued $0.5 million for the payment of interest on the Balance Sheets.

Tax years 2018 and forward remain subject to examination by the Internal Revenue Service and state taxing authorities.
(4) Equity Investments

The following table presents our equity investments reflected in the investments in subsidiary companies on the Balance Sheets (in thousands):

March 31,2022December 31, 2021
Havre Pipeline Company, LLC$11,959 $12,130 
Canadian Montana Pipeline Corporation4,890 4,867 
NorthWestern Energy Solutions, Inc.4,694 4,126 
NorthWestern Services, LLC2,071 2,065 
Risk Partners Assurance, Ltd.1,175 1,190 
Total Investments in Subsidiary Companies$24,789 $24,378 
(5) Comprehensive Income

The following tables display the components of Other Comprehensive Income, after-tax, and the related tax effects (in thousands):

Three Months Ended
March 31,2022March 31,2021
Before-
Tax Amount
Tax
Expense (Benefit)
Net-of-
Tax Amount
Before-
Tax Amount
Tax
Expense (Benefit)
Net-of-
Tax Amount
Foreign currency translation adjustment$(1)$— $(1)$(76)$— $(76)
Reclassification of net income (loss) on derivative instruments153 (40)113 153 (40)113 
Postretirement medical liability adjustment(212)54 (158)(212)54 (158)
Other comprehensive income$(60)$14 $(46)$(135)$14 $(121)

Balances by classification included within accumulated other comprehensive income (AOCI) on the Balance Sheets are as follows, net of tax (in thousands):
March 31,2022December 31, 2021
Foreign currency translation$1,442 $1,443 
Derivative instruments designated as cash flow hedges(8,014)(8,127)
Postretirement medical plans1,358 1,516 
Accumulated other comprehensive income$(5,214)$(5,168)

The following tables display the changes in AOCI by component, net of tax (in thousands):


Three Months Ended March 31,2022
Affected Line Item in the Statements of Income
Interest Rate Derivative Instruments
Designated as Cash Flow Hedges
Postretirement Medical Plans
Foreign
Currency
Translation
Total
Beginning balance$(8,127)$1,516 $1,443 $(5,168)
Other comprehensive income before reclassifications— — (1)(1)
Amounts reclassified from AOCIInterest on long-term debt113 — — 113 
Amounts reclassified from AOCI— (158)— (158)
Net current-period other comprehensive income113 (158)(1)(46)
Ending balance$(8,014)$1,358 $1,442 $(5,214)

Three Months Ended March 31,2021
Affected Line Item in the Statements of Income
Interest Rate Derivative Instruments
Designated as Cash Flow Hedges
Postretirement Medical Plans
Foreign
Currency
Translation
Total
Beginning balance$(8,579)$1,952 $1,501 $(5,126)
Other comprehensive income before reclassifications— — (76)(76)
Amounts reclassified from AOCIInterest on long-term debt113 — — 113 
Amounts reclassified from AOCI— (158)— (158)
Net current-period other comprehensive income113 (158)(76)(121)
Ending balance$(8,466)$1,794 $1,425 $(5,247)
(6) Financing Activities

On November 17, 2021, we announced a registered public offering of 6,074,767 shares of our common stock at a public offering price of $53.50 per share, for an issuance amount of $325.0 million. In conjunction with this offering, we granted the underwriters an option to purchase up to 911,215 additional shares, which was subsequently exercised in full, for an additional issuance amount of $48.8 million. Of the total 6,985,982 shares of common stock offered, we initially sold 1,401,869 shares, for $75.0 million in gross proceeds, directly to the underwriters in the offering, with cash proceeds received at closing. The remaining 5,584,113 shares were sold under forward sales agreements which provide for settlement on a settlement date or dates to be specified at our discretion, but which is expected to occur on or prior to February 28, 2023. The cumulative shares issued under the forward sales agreement is limited to one and one-half times the base number of shares within the agreement, or 8,376,170 shares.

The forward sales agreements will be physically settled with common shares issued by us, unless we elect to settle the agreements in cash or to net share settle the agreements, subject to certain conditions. On a settlement date or dates, if we decide to physically settle the forward sales agreement, we will issue shares of common stock to the forward purchaser at the then-applicable forward sale price and receive issuance proceeds at that time. The forward sale price will initially be $51.8950 per share, which is subject to adjustment based on a floating interest rate factor equal to the overnight bank funding rate less a spread of 75.00 basis points, and will be subject to decrease on certain dates specified in the forward sale agreement by amounts related to expected dividends on shares of common stock during the term of the forward sale agreement.

At March 31, 2022, the forward agreements could have been settled with physical delivery of 5,584,113 common shares to the banking counterparty in exchange for cash of $282.1 million. The forward instruments could have also been settled at March 31, 2022, with delivery of $41.2 million of cash or 705,342 shares of common stock to the counterparty, if we elected net cash or net share settlement, respectively.
(7) Related Party Transactions

Accounts receivable from and payables to associated companies primarily include intercompany billings for direct charges, overhead, and income tax obligations. The following table reflects our accounts receivable from and accounts payable to associated companies (in thousands):

March 31,2022December 31, 2021
Accounts Receivable from Associated Companies:
Havre Pipeline Company, LLC$3,070 $2,378 
NorthWestern Energy Solutions, Inc.71 71 
Risk Partners Assurance, Ltd.18 18 
$3,159 $2,467 
Accounts Payable to Associated Companies:
NorthWestern Services, LLC$1,850 $1,791 
Canadian Montana Pipeline Corporation2,135 1,860 
$3,985 $3,651 
(8) Employee Benefit Plans

We sponsor and/or contribute to pension and postretirement health care and life insurance benefit plans for eligible employees. Net periodic benefit cost (credit) for our pension and other postretirement plans consists of the following (in thousands):
Pension BenefitsOther Postretirement Benefits
Three Months Ended March 31,Three Months Ended March 31,
2022202120222021
Components of Net Periodic Benefit Cost (Credit)
Service cost$2,884 $3,263 $91 $99 
Interest cost4,668 4,596 91 75 
Expected return on plan assets(6,052)(6,843)(262)(230)
Amortization of prior service credit— — (473)(459)
Recognized actuarial loss (gain)— 1,228 (14)(11)
Net periodic benefit cost (credit)$1,500 $2,244 $(567)$(526)

We have not contributed to our pension plans during the three months ended March 31, 2022. We expect to contribute $11.2 million to our pension plans during the remainder of 2022.
(9) Commitments and Contingencies

Except as set forth below and in Note 2 - Regulatory Matters above, the circumstances set forth in Note 9 - Commitments and Contingencies to the financial statements included in our Annual FERC Form 1 Report for the year ended December 31, 2021 appropriately represent, in all material respects, the current status of our material commitments and contingent liabilities.

ENVIRONMENTAL LIABILITIES AND REGULATION

Environmental Matters

The operation of electric generating, transmission and distribution facilities, and gas gathering, storage, transportation and distribution facilities, along with the development (involving site selection, environmental assessments, and permitting) and construction of these assets, are subject to extensive federal, state, and local environmental and land use laws and regulations. Our activities involve compliance with diverse laws and regulations that address emissions and impacts to the environment, including air and water, protection of natural resources, avian and wildlife. We monitor federal, state, and local environmental initiatives to determine potential impacts on our financial results. As new laws or regulations are implemented, our policy is to assess their applicability and implement the necessary modifications to our facilities or their operation to maintain ongoing compliance.

Our environmental exposure includes a number of components, including remediation expenses related to the cleanup of current or former properties, and costs to comply with changing environmental regulations related to our operations. At present, our environmental reserve, which relates primarily to the remediation of former manufactured gas plant sites owned by us or for which we are responsible, is estimated to range between $24.4 million to $31.0 million. As of March 31, 2022, we had a reserve of approximately $26.4 million, which has not been discounted. Environmental costs are recorded when it is probable we are liable for the remediation and we can reasonably estimate the liability. We use a combination of site investigations and monitoring to formulate an estimate of environmental remediation costs for specific sites. Our monitoring procedures and development of actual remediation plans depend not only on site specific information but also on coordination with the different environmental regulatory agencies in our respective jurisdictions; therefore, while remediation exposure exists, it may be many years before costs are incurred.

Over time, as costs become determinable, we may seek authorization to recover such costs in rates or seek insurance reimbursement as available and applicable; therefore, although we cannot guarantee regulatory recovery, we do not expect these costs to have a material effect on our consolidated financial position or results of operations.
Global Climate Change - National and international actions have been initiated to address global climate change and the contribution of greenhouse gas (GHG) including, most significantly, carbon dioxide (CO2). These actions include legislative proposals, Executive and Environmental Protection Agency (EPA) actions at the federal level, state level activity, investor activism and private party litigation relating to GHG emissions. Coal-fired plants have come under particular scrutiny due to their level of GHG emissions. We have joint ownership interests in four coal-fired electric generating plants, all of which are operated by other companies. We are responsible for our proportionate share of the capital and operating costs while being entitled to our proportionate share of the power generated.

While numerous bills have been introduced that address climate change from different perspectives, Congress has not passed any federal climate change legislation regarding GHG emissions from coal fired plants, and we cannot predict the timing or form of any potential legislation. The Clean Air Act (CAA) confers authority on EPA and the states to regulate certain emissions, including GHGs, from existing sources. Beginning in 2015, EPA sought to use this Section 111(d) authority to issue rules to control GHG emissions from existing power plants. No rule issued by EPA has become effective due to litigation by various states and stakeholders. One of the key issues in the litigation revolves around whether EPA can use its CAA authority to compel fossil fuel sources to curtail operations and invest in renewable and other low carbon energy sources. The litigation culminated in oral argument at the Supreme Court on February 28, 2022 in West Virginia, et al., v. Environmental Protection Agency, et al (Docket No. 20-1530). The outcome of the Supreme Court's decision could affect us as we have interests in coal plants but we cannot predict the outcome of the issues presented to the Supreme Court or their applicability to us.

We cannot predict whether or how GHG emission regulations will be applied to our plants, including any actions taken by the relevant state authorities. In addition, it is unclear how pending or future litigation relating to GHG matters will impact us. As GHG regulations are implemented, it could result in additional compliance costs impacting our future results of operations and financial position if such costs are not recovered through regulated rates. We will continue working with federal and state regulatory authorities, other utilities, and stakeholders to seek relief from any GHG regulations that, in our view, disproportionately impact customers in our region.
Future additional environmental requirements could cause us to incur material costs of compliance, increase our costs of procuring electricity, decrease transmission revenue and impact cost recovery. Technology to efficiently capture, remove and/or sequester such GHG emissions may not be available within a timeframe consistent with the implementation of any such requirements. Physical impacts of climate change also may present potential risks for severe weather, such as droughts, fires, floods, ice storms and tornadoes, in the locations where we operate or have interests. These potential risks may impact costs for electric and natural gas supply and maintenance of generation, distribution, and transmission facilities.

LEGAL PROCEEDINGS

Pacific Northwest Solar Litigation

Pacific Northwest Solar, LLC (PNWS) is a solar qualifying facility (QF) developer seeking to construct small solar facilities in Montana. We began negotiating with PNWS in early 2016 to purchase the output from 21 of its proposed facilities pursuant to our standard QF-1 Tariff, which is applicable to projects no larger than 3 MWs.

On June 16, 2016, however, the Montana Public Service Commission (MPSC) suspended the availability of the QF-1 Tariff standard rates for that category of solar projects, which included the projects proposed by PNWS. The MPSC exempted from the suspension any projects for which a QF had both submitted a signed power purchase agreement and had executed an interconnection agreement with us by June 16, 2016. Although we had signed four power purchase agreements with PNWS as of that date, we had not entered into interconnection agreements with PNWS for any of those projects. As a result, none of the PNWS projects in Montana qualified for the exemption.

In November 2016, PNWS sued us in state court seeking unspecified damages for breach of contract and a judicial declaration that some or all of the 21 proposed power purchase agreements it had proposed to us were in effect despite the MPSC's Order. We removed the state lawsuit to the United States District Court for the District of Montana (Court).
PNWS also requested the MPSC to exempt its projects from the tariff suspension and allow those projects to receive the QF-1 tariff rate that had been in effect prior to the suspension. We joined in PNWS’s request for relief with respect to four of the projects, but the MPSC did not grant any of the relief requested by PNWS or us.

In August 2017, we entered into a non-monetary, partial settlement with PNWS in which PNWS amended its original complaint to limit its claims for enforcement and/or damages to only four of the 21 power purchase agreements. As a result, the damages sought by the plaintiff was reduced to approximately $8.0 million for the alleged breach of the four power purchase agreements. We participated in an unsuccessful mediation on January 24, 2019 and subsequent settlement efforts also have been unsuccessful.

On August 31, 2021, the Court ruled that the four agreements were valid and enforceable contracts and that NorthWestern breached the agreements on June 16, 2016 by refusing to go forward with the projects in spite of the MPSC's Orders. On December 15, 2021, after a three-day trial, the jury determined that PNWS had sustained $0.5 million in damages and the judge subsequently entered judgment against us in that amount.

We filed a post-trial motion on January 13, 2022 seeking to have the judgment set aside. On February 9, 2022, the judge denied our post-trial motion. We filed our Notice of Appeal to the Ninth Circuit Court of Appeals on March 1, 2022, and PNWS filed its Cross-Notice of Appeal on March 9, 2022. The Court of Appeals has set a briefing schedule that extends into September 2022, after which the Court will hear oral arguments before rendering a decision.

The Court of Appeals also encouraged the parties to engage in a voluntary court-supervised mediation, but PNWS has not yet indicated whether it is willing to do so.

State of Montana - Riverbed Rents

On April 1, 2016, the State of Montana (State) filed a complaint on remand (the State’s Complaint) with the Montana First Judicial District Court (State District Court), naming us, along with Talen Montana, LLC (Talen) as defendants. The State claimed it owns the riverbeds underlying 10 of our, and formerly Talen’s, hydroelectric facilities (dams, along with reservoirs and tailraces) on the Missouri, Madison and Clark Fork Rivers, and seeks rents for Talen’s and our use and occupancy of such lands. The facilities at issue include the Hebgen, Madison, Hauser, Holter, Black Eagle, Rainbow, Cochrane, Ryan, and Morony facilities on the Missouri and Madison Rivers and the Thompson Falls facility on the Clark Fork River. We acquired these facilities from Talen in November 2014.

The litigation has a long prior history. In 2012, the United States Supreme Court issued a decision holding that the Montana Supreme Court erred in not considering a segment-by-segment approach to determine navigability and relying on present day recreational use of the rivers. It also held that what it referred to as the Great Falls Reach “at least from the head of the first waterfall to the foot of the last” was not navigable for title purposes, and thus the State did not own the riverbeds in that segment. The United States Supreme Court remanded the case to the Montana Supreme Court for further proceedings not inconsistent with its opinion. Following the 2012 remand, the case laid dormant for four years until the State’s Complaint was filed with the State District Court. On April 20, 2016, we removed the case from State District Court to the United States District Court for the District of Montana (Federal District Court). The State filed a motion to remand. Following briefing and argument, on October 10, 2017, the Federal District Court entered an order denying the State’s motion.

Because the State’s Complaint included a claim that the State owned the riverbeds in the Great Falls Reach, on October 16, 2017, we and Talen renewed our earlier-filed motions seeking to dismiss the portion of the State’s Complaint concerning the Great Falls Reach in light of the United States Supreme Court’s decision. On August 1, 2018, the Federal District Court granted the motions to dismiss the State’s Complaint as it pertains to approximately 8.2 miles of riverbed from “the head of the Black Eagle Falls to the foot of the Great Falls.” In particular, the dismissal pertained to the Black Eagle Dam, Rainbow Dam and reservoir, Cochrane Dam and reservoir, and Ryan Dam and reservoir. While the dismissal of these four facilities may be subject to appeal, that appeal would not likely occur until after judgment in the case. On February 12, 2019, the Federal District Court granted our motion to join the United States as a defendant to the litigation. As a result, on October 31, 2019, the State filed and served an Amended Complaint including the United States as a defendant and removing claims of ownership for the hydroelectric facilities on the Great Falls Reach, except for the Morony and the Black Eagle Developments. We and Talen filed answers to the Amended Complaint on December 13, 2019, and the United States answered on February 5, 2020. A bench trial before the Federal District Court commenced January 4, 2022 and concluded on January 18, 2022. This bench trial addressed the issue of navigability of the segments at issue. Post trial briefing and proposed findings of fact and
conclusions of law have been submitted, and a decision on navigability is expected to follow. Damages were bifurcated by agreement and will be tried separately, should the Federal District Court find any segments navigable.

We dispute the State’s claims and intend to continue to vigorously defend the lawsuit. At this time, we cannot predict an outcome. If the Federal District Court determines the riverbeds are navigable under the remaining six facilities that were not dismissed and if it calculates damages as the State District Court did in 2008, we estimate the annual rents could be approximately $3.8 million commencing when we acquired the facilities in November 2014. We anticipate that any obligation to pay the State rent for use and occupancy of the riverbeds would be recoverable in rates from customers, although there can be no assurances that the MPSC would approve any such recovery.

Colstrip Arbitration and Litigation

As part of the settlement of litigation brought by the Sierra Club and the Montana Environmental Information Center against the owners and operator of Colstrip, the owners of Units 1 and 2 agreed to shut down those units no later than July 2022. In January 2020, the owners of Units 1 and 2 closed those two units. We do not have ownership in Units 1 and 2, and decisions regarding those units, including their shut down, were made by their respective owners. The six owners of Units 3 and 4 currently share the operating costs pursuant to the terms of an operating agreement among them, the Ownership and Operation Agreement (O&O Agreement). Costs of common facilities were historically shared among the owners of all four units. With the closure of Units 1 and 2, we have incurred additional operating costs with respect to our interest in Unit 4 and expect to experience a negative impact on our transmission revenue due to reduced amounts of energy transmitted across our transmission lines. We expect to incorporate any reduction in revenue in our next general electric rate filing, resulting in lower revenue credits to certain customers.

The remaining depreciable life of our investment in Colstrip Unit 4 is through 2042. Recovery of costs associated with the closure of the facility is subject to MPSC approval. Three of the joint owners of Units 3 and 4 are subject to regulation in Washington and in May 2019, the Washington state legislature enacted a statute mandating Washington electric utilities to “eliminate coal-fired resources from [their] allocation of electricity” on or before December 31, 2025, after which date they may no longer include their share of coal-fired resources in their regulated electric supply portfolio. As a result of the Washington legislation, four of the six joint owners of Units 3 and 4 requested the operator prepare a 2021 budget reflecting closure of Units 3 and 4 by 2025, and alternately a closure of Unit 3 by 2025 and a closure of Unit 4 by 2027. Differing viewpoints on closure dates delayed approval of the 2021 budget, until it was approved on March 22, 2021. Budgeting for 2022 was also delayed, with the same four joint owners demanding substantial budget reductions, but was ultimately approved on January 21, 2022. Such budgeting pressures may result in future budgets that may not be sufficient to maintain the reliability of Units 3 and 4.

While we believe closure requires each owner’s consent, there are differences among the owners as to this issue under the O&O Agreement. On March 12, 2021, we initiated an arbitration under the O&O Agreement (the “Arbitration”), which seeks to resolve the primary issue of whether closure of Units 3 and 4 can be accomplished without each joint owner's consent and to clarify the obligations of the joint owners to continue to fund operations until all joint owners agree on closure.

The threat of early closure led the Montana Legislature to enact, and the Montana Governor to sign into law, Senate Bill 265 (SB 265) and Senate Bill 266 (SB 266). SB 265 requires arbitrations involving a Montana electric utility to be heard in Montana before a panel of three arbitrators, which, if enforced, would alter the O&O Agreement’s arbitration provision. SB 266 allows the Montana Attorney General (“Montana AG”) to bring legal action against an owner of a jointly-owned facility who fails or refuses to fund its share of operating costs or who acts to bring about permanent closure of a generating unit of a facility without seeking and obtaining the consent of all co-owners. If an owner is found to have acted willfully in so acting, the Montana AG may seek a daily fine of $100,000 for each violation.

The Arbitration has given rise to three lawsuits challenging the constitutionality of SB 265 and SB 266. The four joint owners from the Pacific Northwest assert the Arbitration must be conducted under the O&O Agreement, with one arbitrator, in Spokane County, Washington, and pursuant to the Washington Arbitration Act. The fifth joint owner asserts the Arbitration must be conducted per the terms of SB 265, which requires the Arbitration be conducted, with three arbitrators, in Montana and pursuant to the Montana Uniform Arbitration Act. The four Pacific Northwest owners have added the Montana AG as a defendant and claim SB 266 is unenforceable as contrary to the U.S. and Montana constitutions. On October 13, 2021 (as clarified on December 17, 2021), the United States District Court for the District of Montana granted a preliminary injunction enjoining the Montana AG from enforcing SB 266. The four Pacific Northwest owners have moved for summary judgment on their claims SB 265 and SB 266 are unconstitutional. We have also moved the court to compel the parties to arbitration. Those motions along with a request by the Montana AG to stay the judicial proceedings were heard by the Magistrate Judge on April 26, 2022.
The three initiated lawsuits do not make direct financial demands, and instead, address issues related to process for the Arbitration and for closure of the facility. The pendency of the lawsuits has delayed commencement of the Arbitration proceedings and thus delayed resolution of the issues we raised when we commenced arbitration. Since the Arbitration was initiated, and despite the litigation, we have worked and continue to work with the other joint owners to arrive at an agreed upon process for the Arbitration.

Colstrip Coal Dust Litigation

On December 14, 2020, a claim was filed against Talen Montana, LLC, the operator of the Colstrip Steam Plant, in the Montana Sixteenth Judicial District Court, Rosebud County, Cause No. CV-20-58. The plaintiffs allege they have suffered adverse effects from coal dust generated during operations associated with the Colstrip Steam Plant. On August 26, 2021, the claim was amended to add in excess of 100 plaintiffs. It also added NorthWestern, as well as the other owners of the Colstrip Steam Plant, and Westmoreland Rosebud Mining LLC, as defendants. Plaintiffs are seeking economic damages, costs and disbursements, punitive damages, attorneys’ fees, and an injunction prohibiting defendants from allowing coal dust to blow onto plaintiffs’ properties.

Since this lawsuit is in its early stages, we are unable to predict outcomes or estimate a range of reasonably possible losses.

Talen Montana Bankruptcy Filing

On May 9, 2022, Talen Montana, LLC (Talen Montana) filed bankruptcy in Houston, Texas, seeking reorganization under Chapter 11. Talen Montana is one of the co-owners of Colstrip Units 1, 2 and 3, and the operator of Units 3 and 4. This bankruptcy filing effects pending legal proceedings in which both NorthWestern and Talen Montana are involved due to the automatic stay. In particular, this filing effects the State of Montana-Riverbed Rents, the Colstrip Arbitration and Litigation and the Colstrip Coal Dust Litigation legal proceedings previously discussed above.

Other Legal Proceedings

We are also subject to various other legal proceedings, governmental audits and claims that arise in the ordinary course of business. In our opinion, the amount of ultimate liability with respect to these other actions will not materially affect our financial position, results of operations, or cash flows.


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
  1. Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate.
  2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges.
  3. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote.
  4. Report data on a year-to-date basis.
Line No.
Item
(a)
Unrealized Gains and Losses on Available-For-Sale Securities
(b)
Minimum Pension Liability Adjustment (net amount)
(c)
Foreign Currency Hedges
(d)
Other Adjustments
(e)
Other Cash Flow Hedges Interest Rate Swaps
(f)
Other Cash Flow Hedges [Specify]
(g)
Totals for each category of items recorded in Account 219
(h)
Net Income (Carried Forward from Page 116, Line 78)
(i)
Total Comprehensive Income
(j)
1
Balance of Account 219 at Beginning of Preceding Year
1,954,756
1,499,267
8,580,168
5,126,145
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
(a)
436,295
(e)
452,130
15,835
3
Preceding Quarter/Year to Date Changes in Fair Value
(c)
57,286
57,286
4
Total (lines 2 and 3)
436,295
57,286
452,130
41,451
63,071,080
63,029,629
5
Balance of Account 219 at End of Preceding Quarter/Year
1,518,461
1,441,981
8,128,038
5,167,596
6
Balance of Account 219 at Beginning of Current Year
1,518,461
1,441,981
8,128,038
5,167,596
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
(b)
158,410
(f)
113,032
45,378
8
Current Quarter/Year to Date Changes in Fair Value
(d)
859
859
9
Total (lines 7 and 8)
158,410
859
113,032
46,237
59,109,835
59,063,598
10
Balance of Account 219 at End of Current Quarter/Year
1,360,051
1,441,122
8,015,006
5,213,833


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
FOOTNOTE DATA

(a) Concept: AccumulatedOtherComprehensiveIncomeLossMinimumPensionLiabilityAdjustmentReclassificationsToNetIncomeLoss
Postretirement medical liability adjustment.
(b) Concept: AccumulatedOtherComprehensiveIncomeLossMinimumPensionLiabilityAdjustmentReclassificationsToNetIncomeLoss
Postretirement medical liability adjustment.
(c) Concept: AccumulatedOtherComprehensiveIncomeLossOtherAdjustmentsToComprehensiveIncomeLossChangesInFairValue
Foreign currency translation adjustment.
(d) Concept: AccumulatedOtherComprehensiveIncomeLossOtherAdjustmentsToComprehensiveIncomeLossChangesInFairValue
Foreign currency translation adjustment.
(e) Concept: AccumulatedOtherComprehensiveIncomeLossOtherCashFlowHedgesInterestRateSwapsReclassificationsToNetIncomeLoss
Reclassification of net losses on derivative instruments.
(f) Concept: AccumulatedOtherComprehensiveIncomeLossOtherCashFlowHedgesInterestRateSwapsReclassificationsToNetIncomeLoss
Reclassification of net losses on derivative instruments.

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION

Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.

Line No.
Classification
(a)
Total Company For the Current Year/Quarter Ended
(b)
Electric
(c)
Gas
(d)
Other (Specify)
(e)
Other (Specify)
(f)
Other (Specify)
(g)
Common
(h)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlantInServiceAbstract
In Service
3
UtilityPlantInServiceClassified
Plant in Service (Classified)
6,390,923,098
4,941,894,689
1,194,703,167
(a)
1,523,174
252,802,068
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
41,938,764
(b)
40,209,537
(c)
1,729,227
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
4,092,785
4,092,785
8
UtilityPlantInServiceClassifiedAndUnclassified
Total (3 thru 7)
6,436,954,647
4,945,987,474
1,194,703,167
1,523,174
40,209,537
1,729,227
252,802,068
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
5,492,985
5,463,119
29,866
11
ConstructionWorkInProgress
Construction Work in Progress
344,195,177
275,433,994
49,361,084
19,400,099
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
686,328,435
686,328,435
13
UtilityPlantAndConstructionWorkInProgress
Total Utility Plant (8 thru 12)
7,472,971,244
5,913,213,022
1,244,094,117
1,523,174
40,209,537
1,729,227
272,202,167
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
2,689,733,593
2,068,482,206
517,084,318
1,057,390
31,664,990
71,444,689
15
UtilityPlantNet
Net Utility Plant (13 less 14)
4,783,237,651
3,844,730,816
727,009,799
465,784
8,544,547
1,729,227
200,757,478
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
2,431,318,030
1,884,880,972
464,711,047
1,057,390
31,664,990
49,003,631
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
45,737,991
45,737,991
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
51,723,517
22,647,179
6,635,280
22,441,058
22
DepreciationAmortizationAndDepletionUtilityPlantInService
Total in Service (18 thru 21)
2,528,779,538
1,907,528,151
517,084,318
1,057,390
31,664,990
71,444,689
23
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract
Leased to Others
24
DepreciationUtilityPlantLeasedToOthers
Depreciation
25
AmortizationAndDepletionUtilityPlantLeasedToOthers
Amortization and Depletion
26
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers
Total Leased to Others (24 & 25)
27
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract
Held for Future Use
28
DepreciationUtilityPlantHeldForFutureUse
Depreciation
29
AmortizationUtilityPlantHeldForFutureUse
Amortization
30
DepreciationAndAmortizationUtilityPlantHeldForFutureUse
Total Held for Future Use (28 & 29)
31
AbandonmentOfLeases
Abandonment of Leases (Natural Gas)
32
AmortizationOfPlantAcquisitionAdjustment
Amortization of Plant Acquisition Adjustment
160,954,055
160,954,055
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Total Accum Prov (equals 14) (22,26,30,31,32)
2,689,733,593
2,068,482,206
517,084,318
1,057,390
31,664,990
71,444,689


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
FOOTNOTE DATA

(a) Concept: UtilityPlantInServiceClassified
This column represents regulated propane.
(b) Concept: UtilityPlantInServicePropertyUnderCapitalLeases
This column represents the write-down of plant values associated with the 2002 acquisition of Montana Operations, and the reduction from fair value to regulated basis associated with the transfer of Colstrip Unit 4 to the regulated utility in 2009.
(c) Concept: UtilityPlantInServicePropertyUnderCapitalLeases
This column represents an electric default supply capacity and energy sales agreement classified as a capital lease.

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
Electric Plant In Service and Accum Provision For Depr by Function
  1. Report below the original cost of plant in service by function. In addition to Account 101, include Account 102, and Account 106. Report in column (b) the original cost of plant in service and in column(c) the accumulated provision for depreciation and amortization by function.
Line No.
Item
(a)
Plant in Service Balance at End of Quarter
(b)
Accumulated Depreciation And Amortization Balance at End of Quarter
(c)
1
Intangible Plant
26,863,205
9,138,667
2
Steam Production Plant
408,343,544
145,694,087
3
Nuclear Production Plant
4
Hydraulic Production - Conventional
579,694,871
140,760,513
5
Hydraulic Production - Pumped Storage
6
Other Production
493,622,819
142,332,790
7
Transmission
1,241,401,695
479,503,566
8
Distribution
2,024,028,045
894,082,173
9
Regional Transmission and Market Operation
10
General
172,033,295
96,016,355
11
TOTAL (Total of lines 1 through 10)
4,945,987,474
1,907,528,151


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
Transmission Service and Generation Interconnection Study Costs
  1. Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies.
  2. List each study separately.
  3. In column (a) provide the name of the study.
  4. In column (b) report the cost incurred to perform the study at the end of period.
  5. In column (c) report the account charged with the cost of the study.
  6. In column (d) report the amounts received for reimbursement of the study costs at end of period.
  7. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.
DescriptionOfStudyPerformed
Description
(a)
StudyCostsIncurred
Costs Incurred During Period
(b)
StudyCostsAccountCharged
Account Charged
(c)
StudyCostsReimbursements
Reimbursements Received During the Period
(d)
StudyCostsAccountReimbursed
Account Credited With Reimbursement
(e)
1
Transmission Studies
2
FAC Studies
54,338
230,684
3
SIS Studies
162,035
291,204
4
Line Interconnection Studies
39,375
64,029
20
Total
255,748
585,917
21
Generation Studies
22
FAC Studies
331,312
1,953,680
23
SIS Studies
287,257
1,513,077
24
FEA Studies
337,080
387,570
25
Optional Studies
79,017
176,852
39
Total
1,034,666
4,031,179
40 Grand Total
1,290,414
4,617,096


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
OTHER REGULATORY ASSETS (Account 182.3)
  1. Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Assets being amortized, show period of amortization.
CREDITS
Line No.
DescriptionAndPurposeOfOtherRegulatoryAssets
Description and Purpose of Other Regulatory Assets
(a)
OtherRegulatoryAssets
Balance at Beginning of Current Quarter/Year
(b)
IncreaseDecreaseInOtherRegulatoryAssets
Debits
(c)
OtherRegulatoryAssetsWrittenOffAccountCharged
Written off During Quarter/Year Account Charged
(d)
OtherRegulatoryAssetsWrittenOffRecovered
Written off During the Period Amount
(e)
OtherRegulatoryAssets
Balance at end of Current Quarter/Year
(f)
1
Flow-through Income Taxes (Montana)
405,926,858
11,589,911
417,516,769
2
Excess Deferred Income Taxes (Montana)
53,729,445
2,135,982
51,593,463
3
Basin Creek Capital Lease (Montana)
5,724,239
189,259
5,534,980
4
BPA Residential Exchange Program (Montana) - Docket 2018.8.49 Order 7630; Annual Amortization
1,264,780
2,562,577
2,575,702
1,251,655
5
Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization
1,668,316
1,668,316
6
FAS 106 (Montana) - Docket 93.6.24 and Docket 2009.9.129
4,476,121
79,257
4,396,864
7
FAS 112 (Montana) - Docket 93.6.24 and Docket 2009.9.129
5,393,028
5,393,028
8
Compensated Absences (Montana) - Docket 97.11.219
11,778,804
139,352
11,918,156
9
Pension Plan (Montana)
93,031,712
1,151,445
91,880,267
10
Montana Consumer Counsel Tax (Montana) - Docket 2018.10.67 - Order 7637
561,618
27,336
588,954
11
Montana Public Service Commission (Montana) - Docket 2017.9.78 - Order 7568
4,283,963
87,640
290,156
4,081,447
12
Natural Gas Transmission Verification Program (Montana) - Docket D2016.11.88
1,151,087
96,012
1,055,075
13
Study of the Costs & Benefits of Customer Generators (Montana)
65,994
60,930
5,064
14
Asset Retirement Obligation (Montana)
12,616,717
603,330
13,220,047
15
Flow-through Income Taxes (South Dakota)
58,736,849
3,336,459
62,073,308
16
Excess Deferred Income Taxes (South Dakota)
7,083,285
74,456
7,008,829
17
Pension Plan (South Dakota)
5,304,230
5,304,230
18
Manufactured Gas Plants (South Dakota) - Docket NG 11-003
11,261,735
77,291
11,184,444
19
Field Inventory (South Dakota) - Docket EL 14-106
352,107
22,479
329,628
20
Asset Retirement Obligation (South Dakota)
737,896
32,686
770,582
44
TOTAL
685,148,784
18,379,291
8,421,285
695,106,790


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
OTHER REGULATORY LIABILITIES (Account 254)
  1. Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Liabilities being amortized, show period of amortization.
DEBITS
Line No.
Description and Purpose of Other Regulatory Liabilities
(a)
Balance at Beginning of Current Quarter/Year
(b)
Account Credited
(c)
Amount
(d)
Credits
(e)
Balance at End of Current Quarter/Year
(f)
1
Excess Deferred Income Taxes (Montana)
137,027,734
2,274,656
134,753,078
2
Deferred Gas Storage Sales (Montana) - Docket D2001.1.1; Amortization 2001 - 2039
7,466,461
105,129
7,361,332
3
Montana Public Service Commission Consumer Counsel Taxes (Montana) - Dockets 2017.9.78 and 2018.10.67
1,694,066
21,265
124,645
1,797,446
4
CTC QF Over/Under Collections (Montana) - Docket 97.9.90 and Docket 2001.1.15; Annual Amortization
29,377
590,909
620,286
5
Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization
571,311
224,080
3,025,916
3,373,147
6
Natural Gas Regulatory Deferrals (Montana)
269,044
126,687
91,223
233,580
7
Excess Deferred Income Taxes (South Dakota)
21,019,531
582,241
20,437,290
8
Current Ad Valorem True-Up (South Dakota) - Docket GE98-001
486,128
58,819
544,947
9
Aberdeen Manufactured Gas Plant (South Dakota) - Docket NG 11-003
508,123
99,005
607,128
10
Tax Cut Jobs Act Deferral (South Dakota) - Docket NG-0095 and GE17-003
155,000
155,000
11
Unbilled Revenues (South Dakota)
16,429,994
2,806,848
13,623,146
41 TOTAL
185,656,769
6,140,906
3,990,517
183,506,380


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
Electric Operating Revenues
  1. The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages.
  2. Report below operating revenues for each prescribed account, and manufactured gas revenues in total.
  3. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month.
  4. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote.
  5. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2.
  6. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.)
  7. See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases.
  8. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts.
  9. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.
Title of Account
(a)
Operating Revenues Year to Date Quarterly/Annual
(b)
Operating Revenues Previous year (no Quarterly)
(c)
MEGAWATT HOURS SOLD Year to Date Quarterly/Annual
(d)
MEGAWATT HOURS SOLD Amount Previous year (no Quarterly)
(e)
AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly)
(f)
AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly)
(g)
1
SalesOfElectricityHeadingAbstract
Sales of Electricity
2
ResidentialSalesAbstract
(440) Residential Sales
116,336,219
1,013,598
3
CommercialAndIndustrialSalesAbstract
(442) Commercial and Industrial Sales
4
CommercialSalesAbstract
Small (or Comm.) (See Instr. 4)
104,626,503
951,108
5
IndustrialSalesAbstract
Large (or Ind.) (See Instr. 4)
18,302,487
191,259
6
PublicStreetAndHighwayLightingAbstract
(444) Public Street and Highway Lighting
3,992,067
10,942
7
OtherSalesToPublicAuthoritiesAbstract
(445) Other Sales to Public Authorities
237,685
1,944
8
SalesToRailroadsAndRailwaysAbstract
(446) Sales to Railroads and Railways
9
InterdepartmentalSalesAbstract
(448) Interdepartmental Sales
220,497
1,928
10
SalesToUltimateConsumersAbstract
TOTAL Sales to Ultimate Consumers
243,715,458
2,170,779
11
SalesForResaleAbstract
(447) Sales for Resale
9,686,325
281,055
12
SalesOfElectricityAbstract
TOTAL Sales of Electricity
253,401,783
2,451,834
13
ProvisionForRateRefundsAbstract
(Less) (449.1) Provision for Rate Refunds
1,980,010
14
RevenuesNetOfProvisionForRefundsAbstract
TOTAL Revenues Before Prov. for Refunds
255,381,793
2,451,834
15
OtherOperatingRevenuesAbstract
Other Operating Revenues
16
ForfeitedDiscounts
(450) Forfeited Discounts
143,365
17
MiscellaneousServiceRevenues
(451) Miscellaneous Service Revenues
45,500
18
SalesOfWaterAndWaterPower
(453) Sales of Water and Water Power
19
RentFromElectricProperty
(454) Rent from Electric Property
1,207,467
20
InterdepartmentalRents
(455) Interdepartmental Rents
21
OtherElectricRevenue
(456) Other Electric Revenues
(a)
701,201
22
RevenuesFromTransmissionOfElectricityOfOthers
(456.1) Revenues from Transmission of Electricity of Others
20,236,657
23
RegionalTransmissionServiceRevenues
(457.1) Regional Control Service Revenues
24
MiscellaneousRevenue
(457.2) Miscellaneous Revenues
25
OtherMiscellaneousOperatingRevenues
Other Miscellaneous Operating Revenues
25.1
OtherMiscellaneousOperatingRevenues
(Less) (449.1) Provision for Rate Refunds
26
OtherOperatingRevenues
TOTAL Other Operating Revenues
20,931,788
27
ElectricOperatingRevenues
TOTAL Electric Operating Revenues
276,313,581
Line12, column (b) includes $
of unbilled revenues.
Line12, column (d) includes
MWH relating to unbilled revenues


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
FOOTNOTE DATA

(a) Concept: OtherElectricRevenue
Q1
Other Electric Revenue
(456)
2022
Ancillary Services:
Scheduling, System Control and Dispatch $ 459,206 
Regulation and Frequency Response 272,361 
Energy Imbalance (1,205,719)
Other Transmission Revenue (1,372,834)
Low Income Housing 823,724 
Steam Sales 299,755 
Sale of Materials 22,023 
Miscellaneous 283 
$ (701,201)

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
  1. The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.
Description of Service
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
TOTAL


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
ELECTRIC PRODUCTION, OTHER POWER SUPPLY EXPENSES, TRANSMISSION AND DISTRIBUTION EXPENSES

Report Electric production, other power supply expenses, transmission, regional market, and distribution expenses through the reporting period.

Line No.
Account
(a)
Year to Date Quarter
(b)
1
PowerProductionExpensesAbstract
1. POWER PRODUCTION AND OTHER SUPPLY EXPENSES
2
SteamPowerGenerationOperationsExpense
Steam Power Generation - Operation (500-509)
15,943,105
3
SteamPowerGenerationMaintenanceExpense
Steam Power Generation – Maintenance (510-515)
2,474,121
4
PowerProductionExpensesSteamPower
Total Power Production Expenses - Steam Power
18,417,226
5
NuclearPowerGenerationOperationsExpense
Nuclear Power Generation – Operation (517-525)
6
NuclearPowerGenerationMaintenanceExpense
Nuclear Power Generation – Maintenance (528-532)
7
PowerProductionExpensesNuclearPower
Total Power Production Expenses - Nuclear Power
8
HydraulicPowerGenerationOperationsExpense
Hydraulic Power Generation – Operation (535-540.1)
3,178,240
9
HydraulicPowerGenerationMaintenanceExpense
Hydraulic Power Generation – Maintenance (541-545.1)
539,178
10
PowerProductionExpensesHydraulicPower
Total Power Production Expenses - Hydraulic Power
3,717,418
11
RentsOtherPowerGeneration
Other Power Generation – Operation (546-550.1)
7,185,544
12
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration
Other Power Generation – Maintenance (551-554.1)
314,640
13
MaintenanceOfMiscellaneousOtherPowerGenerationPlant
Total Power Production Expenses - Other Power
7,500,184
14
OtherPowerSuplyExpensesAbstract
Other Power Supply Expenses
15
PurchasedPower
(555) Purchased Power
67,393,961
15.1
PowerPurchasedForStorageOperations
(555.1) Power Purchased for Storage Operations
16
SystemControlAndLoadDispatchingElectric
(556) System Control and Load Dispatching
86,251
17
OtherExpensesOtherPowerSupplyExpenses
(557) Other Expenses
9,728,510
18
OtherPowerSupplyExpense
Total Other Power Supply Expenses (line 15-17)
57,751,702
19
PowerProductionExpenses
Total Power Production Expenses (Total of lines 4, 7, 10, 13 and 18)
87,386,530
20
TransmissionExpensesAbstract
2. TRANSMISSION EXPENSES
21
TransmissionExpensesOperationAbstract
Transmission Operation Expenses
22
OperationSupervisionAndEngineeringElectricTransmissionExpenses
(560) Operation Supervision and Engineering
1,262,515
24
LoadDispatchReliability
(561.1) Load Dispatch-Reliability
264,162
25
LoadDispatchMonitorAndOperateTransmissionSystem
(561.2) Load Dispatch-Monitor and Operate Transmission System
204,755
26
LoadDispatchTransmissionServiceAndScheduling
(561.3) Load Dispatch-Transmission Service and Scheduling
304,751
27
SchedulingSystemControlAndDispatchServices
(561.4) Scheduling, System Control and Dispatch Services
28
ReliabilityPlanningAndStandardsDevelopment
(561.5) Reliability, Planning and Standards Development
23,048
29
TransmissionServiceStudies
(561.6) Transmission Service Studies
30
GenerationInterconnectionStudies
(561.7) Generation Interconnection Studies
31
ReliabilityPlanningAndStandardsDevelopmentServices
(561.8) Reliability, Planning and Standards Development Services
32
StationExpensesTransmissionExpense
(562) Station Expenses
453,490
32.1
OperationOfEnergyStorageEquipmentTransmissionExpense
(562.1) Operation of Energy Storage Equipment
33
OverheadLineExpense
(563) Overhead Lines Expenses
418,821
34
UndergroundLineExpensesTransmissionExpense
(564) Underground Lines Expenses
35
TransmissionOfElectricityByOthers
(565) Transmission of Electricity by Others
7,332,524
36
MiscellaneousTransmissionExpenses
(566) Miscellaneous Transmission Expenses
39,558
37
RentsTransmissionElectricExpense
(567) Rents
209,864
38
OperationSuppliesAndExpensesTransmissionExpense
(567.1) Operation Supplies and Expenses (Non-Major)
39
TransmissionOperationExpense
TOTAL Transmission Operation Expenses (Lines 22 - 38)
10,513,488
40
TransmissionMaintenanceAbstract
Transmission Maintenance Expenses
41
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses
(568) Maintenance Supervision and Engineering
119,769
42
MaintenanceOfStructuresTransmissionExpense
(569) Maintenance of Structures
9,035
43
MaintenanceOfComputerHardwareTransmission
(569.1) Maintenance of Computer Hardware
787,733
44
MaintenanceOfComputerSoftwareTransmission
(569.2) Maintenance of Computer Software
880
45
MaintenanceOfCommunicationEquipmentElectricTransmission
(569.3) Maintenance of Communication Equipment
46
MaintenanceOfMiscellaneousRegionalTransmissionPlant
(569.4) Maintenance of Miscellaneous Regional Transmission Plant
47
MaintenanceOfStationEquipmentTransmission
(570) Maintenance of Station Equipment
170,517
47.1
MaintenanceOfEnergyStorageEquipmentTransmission
(570.1) Maintenance of Energy Storage Equipment
48
MaintenanceOfOverheadLinesTransmission
(571) Maintenance of Overhead Lines
499,629
49
MaintenanceOfUndergroundLinesTransmission
(572) Maintenance of Underground Lines
50
MaintenanceOfMiscellaneousTransmissionPlant
(573) Maintenance of Miscellaneous Transmission Plant
51
MaintenanceOfTransmissionPlant
(574) Maintenance of Transmission Plant
52
TransmissionMaintenanceExpenseElectric
TOTAL Transmission Maintenance Expenses (Lines 41 – 51)
1,587,563
53
TransmissionExpenses
Total Transmission Expenses (Lines 39 and 52)
12,101,051
54
RegionalMarketExpensesAbstract
3. REGIONAL MARKET EXPENSES
55
RegionalMarketExpensesOperationAbstract
Regional Market Operation Expenses
56
OperationSupervision
(575.1) Operation Supervision
57
DayAheadAndRealTimeMarketAdministration
(575.2) Day-Ahead and Real-Time Market Facilitation
87,010
58
TransmissionRightsMarketAdministration
(575.3) Transmission Rights Market Facilitation
59
CapacityMarketAdministration
(575.4) Capacity Market Facilitation
60
AncillaryServicesMarketAdministration
(575.5) Ancillary Services Market Facilitation
24,860
61
MarketMonitoringAndCompliance
(575.6) Market Monitoring and Compliance
12,430
62
MarketFacilitationMonitoringAndComplianceServices
(575.7) Market Facilitation, Monitoring and Compliance Services
63
RegionalMarketOperationExpense
Regional Market Operation Expenses (Lines 55 - 62)
124,300
64
RegionalMarketExpensesMaintenanceAbstract
Regional Market Maintenance Expenses
65
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses
(576.1) Maintenance of Structures and Improvements
66
MaintenanceOfComputerHardware
(576.2) Maintenance of Computer Hardware
67
MaintenanceOfComputerSoftware
(576.3) Maintenance of Computer Software
68
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses
(576.4) Maintenance of Communication Equipment
69
MaintenanceOfMiscellaneousMarketOperationPlant
(576.5) Maintenance of Miscellaneous Market Operation Plant
70
RegionalMarketMaintenanceExpense
Regional Market Maintenance Expenses (Lines 65-69)
71
RegionalMarketExpenses
TOTAL Regional Control and Market Operation Expenses (Lines 63,70)
124,300
72
DistributionExpensesAbstract
4. DISTRIBUTION EXPENSES
73
DistributionOperationExpensesElectric
Distribution Operation Expenses (580-589)
4,121,690
74
DistributionMaintenanceExpenseElectric
Distribution Maintenance Expenses (590-598)
4,770,726
75
DistributionExpenses
Total Distribution Expenses (Lines 73 and 74)
8,892,416


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
Electric Customer Accts, Service, Sales, Admin and General Expenses

Report the amount of expenses for customer accounts, service, sales, and administrative and general expenses year to date.

Line No.
Account
(a)
Year to Date Quarter
(b)
-
CustomerAccountsExpensesOperationsAbstract
Operation
1
CustomerAccountExpenses
(901-905) Customer Accounts Expenses
2,576,865
2
CustomerServiceAndInformationExpenses
(907-910) Customer Service and Information Expenses
919,713
3
SalesExpenses
(911-917) Sales Expenses
221,798
4
AdministrativeAndGeneralExpensesAbstract
8. ADMINISTRATIVE AND GENERAL EXPENSES
5
AdministrativeAndGeneralExpensesOperationAbstract
Operation
6
AdministrativeAndGeneralSalaries
(920) Administrative and General Salaries
8,210,059
7
OfficeSuppliesAndExpenses
(921) Office Supplies and Expenses
5,842,909
8
AdministrativeExpensesTransferredCredit
(Less) (922) Administrative Expenses Transferred-Credit
1,392,018
9
OutsideServicesEmployed
(923) Outside Services Employed
2,522,554
10
PropertyInsurance
(924) Property Insurance
705,148
11
InjuriesAndDamages
(925) Injuries and Damages
2,417,776
12
EmployeePensionsAndBenefits
(926) Employee Pensions and Benefits
5,266,457
13
FranchiseRequirements
(927) Franchise Requirements
14
RegulatoryCommissionExpenses
(928) Regulatory Commission Expenses
644,199
15
DuplicateChargesCredit
(929) (Less) Duplicate Charges-Cr.
16
GeneralAdvertisingExpenses
(930.1) General Advertising Expenses
72,723
17
MiscellaneousGeneralExpenses
(930.2) Miscellaneous General Expenses
4,643,897
18
RentsAdministrativeAndGeneralExpense
(931) Rents
275,077
19
AdministrativeAndGeneralOperationExpense
TOTAL Operation (Total of lines 6 thru 18)
29,208,781
20
AdministrativeAndGeneralExpensesMaintenanceAbstract
Maintenance
21
MaintenanceOfGeneralPlant
(935) Maintenance of General Plant
1,220,435
22
AdministrativeAndGeneralExpenses
TOTAL Administrative and General Expenses (Total of lines 19 and 21)
30,429,216


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
  1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
  3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
  4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
  6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
  7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
  8. Report in column (i) and (j) the total megawatthours received and delivered.
  9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
  11. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Line No.
PaymentByCompanyOrPublicAuthority
Payment By (Company of Public Authority) (Footnote Affiliation)
(a)
TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName
Energy Received From (Company of Public Authority) (Footnote Affiliation)
(b)
TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName
Energy Delivered To (Company of Public Authority) (Footnote Affiliation)
(c)
StatisticalClassificationCode
Statistical Classification
(d)
RateScheduleTariffNumber
Ferc Rate Schedule of Tariff Number
(e)
TransmissionPointOfReceipt
Point of Receipt (Substation or Other Designation)
(f)
TransmissionPointOfDelivery
Point of Delivery (Substation or Other Designation)
(g)
BillingDemand
Billing Demand (MW)
(h)
TransmissionOfElectricityForOthersEnergyReceived
Megawatt Hours Received
(i)
TransmissionOfElectricityForOthersEnergyDelivered
Megawatt Hours Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
RevenuesFromTransmissionOfElectricityForOthers
Total Revenues ($) (k+l+m)
(n)
1
MONTANA CHOICE TRANSMISSION
2
Ash Grove Cement
Energy Keepers Inc.
Ash Grove Cement
Kerr
Clancy, MT
7
8,798
8,798
59,943
59,943
3
Aspen Air U.S., LLC
Talen Energy
Aspen Air Corporation
Colstrip
Billings, MT
11
13,058
13,058
61,771
61,771
4
Barretts Minerals, Inc.
Energy Keepers inc.
Barretts Minerals, Inc.
Kerr
Dillon, MT
6
7,920
7,920
48,012
48,012
5
Beartooth Electric Cooperative, Inc.
WAPA
Beartooth Electric Cooperative, Inc.
Fort Peck
Various in Montana
18
26,430
26,430
171,193
171,193
6
Benefis Health Systems
Energy Keepers inc.
Benefis Health Systems
Kerr
Various in Montana
7
8,216
8,216
61,310
61,310
7
Big Horn County Electric Coop. Inc.
WAPA
Big Horn County Electric Coop. Inc.
Various & Great Falls
Various in Montana
18
20,838
20,838
147,232
147,232
8
Bonneville Power Administration
BPA
Bonneville Power Administration
BPAT.NWMT
Various in Montana
185
258,492
258,492
1,142,338
1,142,338
9
Basin Electric Power Cooperative
Morgan Stanley, Talen & WAPA
Basin Electric Power Cooperative
Various in Montana
Various NWMT & WAUW
181
238,805
238,805
1,599,780
1,599,780
10
Basin Electric Power Cooperative
Basin Electric & WAPA
Basin Electric Power Cooperative
Crossover
Various NWMT & WAUW
15
23,651
23,651
144,880
144,880
11
CHS, Inc.
Morgan Stanley
CHS, Inc.
MATL.NWMT
Various in Montana
58
93,135
93,135
537,657
537,657
12
City of Great Falls
Energy Keepers Inc.
City of Great Falls
Kerr
Various in Montana
6
4,427
4,427
33,244
33,244
13
Talen Montana, LLC
Avista Energy
Colstrip Steam Electric Station
Colstrip
Nichols Pump Sub
10
6,499
6,499
50,995
50,995
14
Atlas Power, LLC
Tenaska
Atlas Power, LLC
BPAT.NWMT
Butte, MT
75
43,097
43,097
226,624
226,624
15
Phillips 66 Company
Shell Energy
Phillips 66 Company
BPAT.NWMT
Various in Montana
70
117,711
117,711
685,397
685,397
16
ExxonMobil Corporation
Talen Energy
ExxonMobil Corporation
Colstrip
Billings, MT
35
63,184
63,184
366,083
366,083
17
General Mills Operations, LLC
Talen Energy
General Mills Operations, LLC
Colstrip
Great Falls, MT
4
4,795
4,795
30,927
30,927
18
Great Falls Public Schools
Energy Keepers Inc.
Great Falls Public Schools
Kerr
Great Falls, MT
3
2,679
2,679
17,354
17,354
19
GCC Three Forks, LLC
Energy Keepers Inc.
GCC Three Forks, LLC
Kerr
Three Forks, MT
8
8,716
8,716
62,939
62,939
20
Magris Talc USA, Inc.
Energy Keepers Inc.
Imerys Talc America, Inc.
Kerr
Three Forks, MT
6
7,235
7,235
49,226
49,226
21
Suiza Dairy Group, LLC
Talen Energy
Suiza Dairy Group, LLC
Colstrip
Various in Montana
2
1,547
1,547
11,024
11,024
22
Calumet Refining, LLC
Talen Energy
Calumet Montana Refining Company, Inc.
Colstrip
Great Falls, MT
25
28,252
28,252
164,464
164,464
23
Montana Resources
Energy Keepers Inc.
Montana Resources
BPAT.NWMT&Kerr
Butte, MT
50
90,338
90,338
555,139
555,139
24
REC Silicon Company
Morgan Stanley
REC Silicon Company
Hardin
Butte, MT
117
164,133
164,133
823,689
823,689
25
Roseburg Forest Products Company
Talen Energy
Roseburg Forest Products Company
Colstrip
Missoula, MT
8
12,796
12,796
79,427
79,427
26
Sibanye-Stillwater
Energy Keepers Inc.
Stillwater Mining Company
Kerr
Various in Montana
46
72,258
72,258
412,070
412,070
27
Town of Philipsburg
Town of Philipsburg
Town of Philipsburg
Philipsburg Substation
Philipsburg, MT
199
199
1,207
1,207
28
Western Area Power Administration
WAPA
Western Area Power Administration
Crossover
Various NWMT & WAUW
4
2
2
9,326
9,326
29
Montana State University - Bozeman
WAPA
Montana State University - Bozeman
Fort Peck West
Great Falls, MT
4
5,059
5,059
26,363
26,363
30
Western Area Power Administration
WAPA
Malmstrom Air Force Base
Fort Peck West
Great Falls, MT
4
7,109
7,109
44,765
44,765
31
MONTANA POINT-TO-POINT
32
Avista Corporation
AVA
AVA
COLSTRIP
AVAT.NWMT
0
940
940
5,527
5,527
33
Avista Corporation
AVA
AVA
COLSTRIP
AVAT.NWMT
0
37,425
37,425
220,101
220,101
34
Avista Corporation
NWMT
AVA
COLSTRIP
AVAT.NWMT
0
56
56
329
329
35
Avista Corporation
NWMT
AVA
NWMTIMBALANC
AVAT.NWMT
0
100
100
588
588
36
Basin Electric Power Cooperative
NWMT
PACE
BGI
YTP
0
288
288
1,693
1,693
37
Basin Electric Power Cooperative
NWMT
PACE
JUDITHGAP
YTP
0
13
13
76
76
38
Basin Electric Power Cooperative
NWMT
PPW
COLSTRIP
YTP
0
186
186
1,094
1,094
39
Basin Electric Power Cooperative
PPW
NWMT
YTP
NWMT.SYSTEM
0
111
111
653
653
40
Basin Electric Power Cooperative
PPW
WAPA
YTP
CROSSOVER
0
8,139
8,139
47,857
47,857
41
Basin Electric Power Cooperative
PPW
WAPA
YTP
GREATFALLS
0
323
323
1,899
1,899
42
Basin Electric Power Cooperative
WAPA
PPW
CROSSOVER
YTP
0
309
309
1,817
1,817
43
Basin Electric Power Cooperative
WAPA
WAPA
CROSSOVER
GREATFALLS
31
66,929
66,929
397,529
397,529
44
Black Hills Power Inc.
AVA
PPW
AVAT.NWMT
YTP
0
20
20
118
118
45
Black Hills Power Inc.
BPAT
PPW
BPAT.NWMT
YTP
0
75
75
441
441
46
Black Hills Power Inc.
NWMT
PPW
COLSTRIP
YTP
0
250
250
1,470
1,470
47
Black Hills Power Inc.
WAPA
PPW
CROSSOVER
YTP
0
154
154
906
906
48
Bonneville Power Administration
BPAT
PPW
BPAT.NWMT
BRDY
0
1,697
1,697
9,978
9,978
49
Bonneville Power Administration
BPAT
PPW
BPAT.NWMT
YTP
0
51
51
300
300
50
Bonneville Power Administration
BPAT
WAPA
BPAT.NWMT
GREATFALLS
0
1,548
1,548
9,102
9,102
51
Brookfield Renewable Trading and Marketing LP
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
253
253
1,488
1,488
52
Brookfield Renewable Trading and Marketing LP
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
8,400
8,400
49,300
49,300
53
Brookfield Renewable Trading and Marketing LP
NWMT
WAPA
COLSTRIP
CROSSOVER
0
138
138
811
811
54
ConocoPhillips
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
487
487
2,864
2,864
55
Cycle Power Partners, LLC
NWMT
PACE
HORSESHOE
BRDY
0
1,650
1,650
9,702
9,702
56
Cycle Power Partners, LLC
NWMT
PACE
HORSESHOE
JEFF
0
7,862
7,862
46,229
46,229
57
Dynasty Power Inc.
BPAT
PPW
BPAT.NWMT
BRDY
0
374
374
2,199
2,199
58
Dynasty Power Inc.
BPAT
PPW
BPAT.NWMT
YTP
0
1,083
1,083
6,368
6,368
59
Dynasty Power Inc.
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
1,502
1,502
8,832
8,832
60
Dynasty Power Inc.
PPW
BPAT
BRDY
BPAT.NWMT
0
281
281
1,652
1,652
61
Dynasty Power Inc.
PPW
BPAT
YTP
BPAT.NWMT
0
810
810
4,763
4,763
62
Dynasty Power Inc.
PPW
PPW
YTP
BRDY
0
85
85
500
500
63
Dynasty Power Inc.
PPW
WAPA
YTP
CROSSOVER
0
25
25
147
147
64
Dynasty Power Inc.
WAPA
BPAT
CROSSOVER
BPAT.NWMT
0
396
396
2,328
2,328
65
Dynasty Power Inc.
WAPA
PPW
CROSSOVER
BRDY
0
500
500
2,940
2,940
66
EDF Trading North America, LLC
AVA
AVA
COLSTRIP
AVAT.NWMT
0
936
936
5,504
5,504
67
EDF Trading North America, LLC
BPAT
NWMT
BPAT.NWMT
COLSTRIP
0
223
223
1,311
1,311
68
EDF Trading North America, LLC
BPAT
NWMT
BPAT.NWMT
NWMT.SYSTEM
0
450
450
2,646
2,646
69
EDF Trading North America, LLC
NWMT
BPAT
COLSTRIP
BPAT.NWMT
0
10,367
10,367
60,958
60,958
70
EDF Trading North America, LLC
NWMT
BPAT
COLSTRIP
BPAT.NWMT
0
4,800
4,800
28,200
28,200
71
EDF Trading North America, LLC
NWMT
NWMT
COLSTRIP
COLSTRIP
0
190
190
1,117
1,117
72
EDF Trading North America, LLC
NWMT
NWMT
COLSTRIP
MATL.NWMT
0
40
40
235
235
73
EDF Trading North America, LLC
NWMT
PPW
COLSTRIP
BRDY
0
450
450
2,646
2,646
74
EDF Trading North America, LLC
NWMT
PPW
COLSTRIP
YTP
0
1,215
1,215
7,144
7,144
75
EDF Trading North America, LLC
NWMT
PPW
COLSTRIP
BRDY
0
8,400
8,400
49,350
49,350
76
Energy Keepers FIP
NWMT
BPAT
KERR
BPAT.NWMT
12
25,908
25,908
66,289
66,289
77
Energy Keepers Inc.
BPAT
PPW
BPAT.NWMT
YTP
0
1,800
1,800
10,575
10,575
78
Energy Keepers Inc.
NWMT
AVA
KERR
AVAT.NWMT
0
140
140
823
823
79
Energy Keepers Inc.
NWMT
BPAT
KERR
BPAT.NWMT
40
86,360
86,360
512,940
512,940
80
Energy Keepers Inc.
NWMT
BPAT
KERR
BPAT.NWMT
0
528
528
3,105
3,105
81
Energy Keepers Inc.
NWMT
BPAT
KERR
BPAT.NWMT
0
2,184
2,184
12,831
12,831
82
Energy Keepers Inc.
NWMT
PACE
KERR
BRDY
0
1,810
1,810
10,641
10,641
83
Energy Keepers Inc.
NWMT
PACE
KERR
BRDY
0
18,431
18,431
108,429
108,429
84
Energy Keepers Inc.
NWMT
PACE
KERR
JEFF
0
2,616
2,616
15,369
15,369
85
Energy Keepers Inc.
NWMT
PACE
KERR
YTP
0
672
672
3,948
3,948
86
Energy Keepers Inc.
PPW
BPAT
YTP
BPAT.NWMT
0
131
131
87
Guzman Energy, LLC
AVA
PPW
AVAT.NWMT
BRDY
0
470
470
2,764
2,764
88
Guzman Energy, LLC
AVA
PPW
AVAT.NWMT
YTP
0
132
132
776
776
89
Guzman Energy, LLC
BPAT
AVA
BPAT.NWMT
AVAT.NWMT
0
70
70
412
412
90
Guzman Energy, LLC
BPAT
PPW
BPAT.NWMT
BRDY
0
1,091
1,091
6,415
6,415
91
Guzman Energy, LLC
BPAT
PPW
BPAT.NWMT
YTP
0
2,342
2,342
13,771
13,771
92
Guzman Energy, LLC
BPAT
PPW
BPAT.NWMT
YTP
0
2,400
2,400
14,100
14,100
93
Guzman Energy, LLC
NWMT
AVA
NWMTIMBALANC
AVAT.NWMT
0
4
4
24
24
94
Guzman Energy, LLC
NWMT
PPW
COLSTRIP
BRDY
0
270
270
1,588
1,588
95
Guzman Energy, LLC
NWMT
PPW
COLSTRIP
YTP
0
365
365
2,146
2,146
96
Guzman Energy, LLC
PPW
AVA
YTP
AVAT.NWMT
0
343
343
2,017
2,017
97
Guzman Energy, LLC
PPW
AVA
BRDY
AVAT.NWMT
0
2,450
2,450
14,086
14,086
98
Guzman Energy, LLC
PPW
AVA
YTP
AVAT.NWMT
0
3,969
3,969
22,819
22,819
99
Guzman Energy, LLC
PPW
BPAT
BRDY
BPAT.NWMT
0
485
485
2,852
2,852
100
Guzman Energy, LLC
PPW
BPAT
YTP
BPAT.NWMT
0
1,982
1,982
11,654
11,654
101
Guzman Energy, LLC
PPW
BPAT
YTP
BPAT.NWMT
0
2,450
2,450
14,086
14,086
102
Guzman Energy, LLC
PPW
PPW
YTP
BRDY
0
25
25
147
147
103
Idaho Power Company
AVA
PPW
AVAT.NWMT
BRDY
0
12,000
12,000
70,500
70,500
104
Idaho Power Company
PPW
IPCO
JEFF
TNDY
0
624
624
3,666
3,666
105
Macquarie Energy, LLC
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
800
800
4,704
4,704
106
Macquarie Energy, LLC
NWMT
BPA
BGI
BPAT.NWMT
0
480
480
2,822
2,822
107
Macquarie Energy, LLC
NWMT
BPA
BGI
BPAT.NWMT
0
1,200
1,200
7,050
7,050
108
Macquarie Energy, LLC
NWMT
BPAT
TFALLS
BPAT.NWMT
0
160
160
941
941
109
Macquarie Energy, LLC
NWMT
PACE
TFALLS
BRDY
0
400
400
2,352
2,352
110
Macquarie Energy, LLC
NWMT
WAPA
COLSTRIP
CROSSOVER
0
6,480
6,480
38,070
38,070
111
Macquarie Energy, LLC
PPW
WAPA
YTP
CROSSOVER
0
600
600
3,525
3,525
112
Mercuria Energy America, LLC
PPW
BPAT
YTP
BPAT.NWMT
0
1
1
6
6
113
Morgan Stanley Capital Group, Inc.
AVA
NWMT
AVAT.NWMT
MATL.NWMT
0
320
320
1,882
1,882
114
Morgan Stanley Capital Group, Inc.
AVA
NWMT
AVAT.NWMT
MATL.NWMT
0
6,477
6,477
38,475
38,475
115
Morgan Stanley Capital Group, Inc.
BPAT
GWA
BPAT.NWMT
GLWND1
0
705
705
4,145
4,145
116
Morgan Stanley Capital Group, Inc.
BPAT
GWA
BPAT.NWMT
GLWND2
0
277
277
1,629
1,629
117
Morgan Stanley Capital Group, Inc.
BPAT
NWMT
BPAT.NWMT
MATL.NWMT
0
42,323
42,323
248,859
248,859
118
Morgan Stanley Capital Group, Inc.
BPAT
NWMT
BPAT.NWMT
MATL.NWMT
0
112,708
112,708
668,685
668,685
119
Morgan Stanley Capital Group, Inc.
BPAT
PPW
BPAT.NWMT
BRDY
0
920
920
5,410
5,410
120
Morgan Stanley Capital Group, Inc.
BPAT
PPW
BPAT.NWMT
JEFF
0
272
272
1,599
1,599
121
Morgan Stanley Capital Group, Inc.
BPAT
PPW
BPAT.NWMT
BRDY
0
1,680
1,680
9,870
9,870
122
Morgan Stanley Capital Group, Inc.
BPAT
PPW
BPAT.NWMT
JEFF
0
33,711
33,711
199,320
199,320
123
Morgan Stanley Capital Group, Inc.
GWA
AVA
GLWND1
AVAT.NWMT
0
31
31
182
182
124
Morgan Stanley Capital Group, Inc.
GWA
AVA
GLWND2
AVAT.NWMT
0
60
60
353
353
125
Morgan Stanley Capital Group, Inc.
GWA
BPAT
GLWND1
BPAT.NWMT
0
15,344
15,344
90,183
90,183
126
Morgan Stanley Capital Group, Inc.
GWA
BPAT
GLWND2
BPAT.NWMT
0
11,977
11,977
70,381
70,381
127
Morgan Stanley Capital Group, Inc.
GWA
BPAT
GLWND1
BPAT.NWMT
0
43,275
43,275
257,925
257,925
128
Morgan Stanley Capital Group, Inc.
GWA
BPAT
GLWND2
BPAT.NWMT
0
22,070
22,070
132,000
132,000
129
Morgan Stanley Capital Group, Inc.
GWA
NWMT
GLWND1
MATL.NWMT
0
7,285
7,285
42,836
42,836
130
Morgan Stanley Capital Group, Inc.
GWA
NWMT
GLWND1
NWMT.SYSTEM
0
57
57
335
335
131
Morgan Stanley Capital Group, Inc.
GWA
NWMT
GLWND2
MATL.NWMT
0
2,582
2,582
15,182
15,182
132
Morgan Stanley Capital Group, Inc.
GWA
NWMT
GLWND2
NWMT.SYSTEM
0
96
96
564
564
133
Morgan Stanley Capital Group, Inc.
GWA
NWMT
GLWND2
NWMT.SYSTEM
0
12,828
12,828
76,803
76,803
134
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND1
BRDY
0
5,348
5,348
31,438
31,438
135
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND1
JEFF
0
3,721
3,721
21,870
21,870
136
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND1
YTP
0
456
456
2,679
2,679
137
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND2
BRDY
0
2,960
2,960
17,395
17,395
138
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND2
JEFF
0
1,549
1,549
9,105
9,105
139
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND2
YTP
0
25
25
147
147
140
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND1
BRDY
0
18,144
18,144
106,596
106,596
141
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND1
JEFF
0
23,232
23,232
136,488
136,488
142
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND2
BRDY
0
2,232
2,232
13,113
13,113
143
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND2
JEFF
0
10,800
10,800
63,450
63,450
144
Morgan Stanley Capital Group, Inc.
GWA
WAPA
GLWND1
CROSSOVER
0
482
482
2,834
2,834
145
Morgan Stanley Capital Group, Inc.
NWMT
AVA
MATL.NWMT
AVAT.NWMT
0
365
365
2,146
2,146
146
Morgan Stanley Capital Group, Inc.
NWMT
AVA
MATL.NWMT
AVAT.NWMT
0
6,477
6,477
38,475
38,475
147
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
COLSTRIP
BPAT.NWMT
0
234
234
1,376
1,376
148
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
HARDIN
BPAT.NWMT
0
881
881
5,180
5,180
149
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
KERR
BPAT.NWMT
0
30
30
176
176
150
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
0
27,851
27,851
163,694
163,694
151
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
NWMTIMBALANC
BPAT.NWMT
0
50
50
294
294
152
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
0
66,934
66,934
396,906
396,906
153
Morgan Stanley Capital Group, Inc.
NWMT
GWA
COLSTRIP
GLWND1
0
4
4
24
24
154
Morgan Stanley Capital Group, Inc.
NWMT
GWA
MATL.NWMT
GLWND1
0
294
294
1,729
1,729
155
Morgan Stanley Capital Group, Inc.
NWMT
GWA
MATL.NWMT
GLWND2
0
12
12
71
71
156
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
COLSTRIP
MATL.NWMT
0
2,136
2,136
12,553
12,553
157
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
HARDIN
MATL.NWMT
0
538
538
3,163
3,163
158
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
KERR
MATL.NWMT
0
119
119
700
700
159
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
CANYONFERRY
MATL.NWMT
0
2,640
2,640
15,510
15,510
160
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
COLSTRIP
MATL.NWMT
0
65,616
65,616
381,462
381,462
161
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
HARDIN
MATL.NWMT
0
121
121
705
705
162
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
KERR
MATL.NWMT
0
3,023
3,023
17,484
17,484
163
Morgan Stanley Capital Group, Inc.
NWMT
PACE
MATL.NWMT
BRDY
0
12,226
12,226
71,846
71,846
164
Morgan Stanley Capital Group, Inc.
NWMT
PACE
MATL.NWMT
JEFF
0
18,873
18,873
110,894
110,894
165
Morgan Stanley Capital Group, Inc.
NWMT
PACE
MATL.NWMT
YTP
0
750
750
4,406
4,406
166
Morgan Stanley Capital Group, Inc.
NWMT
PACE
MATL.NWMT
BRDY
0
46,464
46,464
272,976
272,976
167
Morgan Stanley Capital Group, Inc.
NWMT
PACE
MATL.NWMT
JEFF
0
6,216
6,216
36,519
36,519
168
Morgan Stanley Capital Group, Inc.
NWMT
PACE
MATL.NWMT
YTP
0
600
600
3,525
3,525
169
Morgan Stanley Capital Group, Inc.
NWMT
WAUW
MATL.NWMT
CROSSOVER
0
538
538
3,163
3,163
170
Morgan Stanley Capital Group, Inc.
NWMT
WAUW
MATL.NWMT
GREATFALLS
0
18
18
106
106
171
Morgan Stanley Capital Group, Inc.
PACE
NWMT
BRDY
MATL.NWMT
0
265
265
1,558
1,558
172
Morgan Stanley Capital Group, Inc.
PACE
NWMT
YTP
MATL.NWMT
0
59,576
59,576
354,825
354,825
173
Morgan Stanley Capital Group, Inc.
PPW
BPAT
BRDY
BPAT.NWMT
0
15
15
88
88
174
Morgan Stanley Capital Group, Inc.
WAPA
AVA
GREATFALLS
AVAT.NWMT
0
148
148
870
870
175
Morgan Stanley Capital Group, Inc.
WAPA
BPAT
GREATFALLS
BPAT.NWMT
0
6,675
6,675
39,249
39,249
176
Morgan Stanley Capital Group, Inc.
WAPA
PPW
GREATFALLS
BRDY
0
1,061
1,061
6,239
6,239
177
Morgan Stanley Capital Group, Inc.
WAPA
PPW
GREATFALLS
JEFF
0
547
547
3,216
3,216
178
Morgan Stanley Capital Group, Inc.
WAPA
PPW
GREATFALLS
YTP
0
90
90
529
529
179
Morgan Stanley Capital Group, Inc.
WAPA
WAPA
GREATFALLS
CROSSOVER
0
200
200
1,176
1,176
180
Morgan Stanley Capital Group, Inc.
WAUW
NWMT
CROSSOVER
MATL.NWMT
0
272
272
1,599
1,599
181
Morgan Stanley Capital Group, Inc.
WAUW
NWMT
GREATFALLS
MATL.NWMT
0
17,010
17,010
100,019
100,019
182
Morgan Stanley Capital Group, Inc.
WAUW
NWMT
CROSSOVER
MATL.NWMT
0
18,550
18,550
106,875
106,875
183
Naturener Power Watch, LLC
GWA
GWA
GLWND1
GLWND2
0
10,795
10,795
64,125
64,125
184
PacifiCorp
PPW
NWMT
MLCK
JEFF
0
294
294
1,729
1,729
185
Portland General Electric Company
NWMT
BPAT
COLSTRIP
BPAT.NWMT
0
1,775
1,775
10,437
10,437
186
Powerex Corporation
BPAT
PPW
BPAT.NWMT
BRDY
0
200
200
1,176
1,176
187
Powerex Corporation
BPAT
PPW
BPAT.NWMT
YTP
0
1,550
1,550
9,114
9,114
188
Powerex Corporation
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
2,296
2,296
13,500
13,500
189
Powerex Corporation
PPW
BPAT
BRDY
BPAT.NWMT
0
450
450
2,646
2,646
190
Powerex Corporation
PPW
BPAT
YTP
BPAT.NWMT
0
5,136
5,136
30,200
30,200
191
Powerex Corporation
WAPA
BPAT
CROSSOVER
BPAT.NWMT
0
2,621
2,621
15,411
15,411
192
Public Service Company of Colorado
PPW
WAPA
YTP
CROSSOVER
0
871
871
5,121
5,121
193
Public Service Company of Colorado
WAPA
PPW
CROSSOVER
YTP
0
962
962
5,657
5,657
194
Rainbow Electric Marketing Corp.
AVA
PPW
AVAT.NWMT
YTP
0
150
150
882
882
195
Rainbow Electric Marketing Corp.
AVA
WAPA
AVAT.NWMT
CROSSOVER
0
694
694
4,081
4,081
196
Rainbow Electric Marketing Corp.
BPAT
PPW
BPAT.NWMT
YTP
0
480
480
2,822
2,822
197
Rainbow Electric Marketing Corp.
BPAT
PPW
BPAT.NWMT
BRDY
0
2,400
2,400
14,100
14,100
198
Rainbow Electric Marketing Corp.
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
656
656
3,857
3,857
199
Rainbow Electric Marketing Corp.
NWMT
PPW
COLSTRIP
YTP
0
240
240
1,411
1,411
200
Rainbow Electric Marketing Corp.
NWMT
PPW
COLSTRIP
YTP
0
240
240
1,410
1,410
201
Rainbow Electric Marketing Corp.
PPW
WAPA
YTP
CROSSOVER
0
1,070
1,070
6,292
6,292
202
Shell Energy North America
BPAT
PPW
BPAT.NWMT
BRDY
0
184
184
1,082
1,082
203
Shell Energy North America
BPAT
PPW
BPAT.NWMT
YTP
0
180
180
1,058
1,058
204
Shell Energy North America
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
15,892
15,892
93,445
93,445
205
Shell Energy North America
NWMT
BPAT
KERR
BPAT.NWMT
0
24
24
141
141
206
Shell Energy North America
PPW
AVA
BRDY
AVAT.NWMT
0
2,450
2,450
14,086
14,086
207
Shell Energy North America
PPW
AVA
YTP
AVAT.NWMT
0
531
531
3,122
3,122
208
Shell Energy North America
PPW
AVA
YTP
AVAT.NWMT
0
75
75
209
Shell Energy North America
PPW
BPAT
YTP
BPAT.NWMT
0
4,674
4,674
27,483
27,483
210
Shell Energy North America
PPW
PPW
YTP
BRDY
0
9
9
53
53
211
Shell Energy North America
PPW
WAPA
BRDY
CROSSOVER
0
50
50
294
294
212
Shell Energy North America
WAPA
AVA
CROSSOVER
AVAT.NWMT
0
243
243
1,429
1,429
213
Shell Energy North America
WAPA
BPAT
CROSSOVER
BPAT.NWMT
0
21,510
21,510
126,479
126,479
214
Shell Energy North America
WAPA
PPW
CROSSOVER
BRDY
0
288
288
1,693
1,693
215
Shell Energy North America
WAPA
PPW
CROSSOVER
JEFF
0
281
281
1,652
1,652
216
Talen Energy Marketing, LLC
NWMT
BPAT
GTFALLSNWMT
BPAT.NWMT
0
25
25
217
Tenaska Power Services Co.
NWMT
BPAT
COLSTRIP
BPAT.NWMT
0
130
130
764
764
218
Tenaska Power Services Co.
NWMT
PPW
COLSTRIP
YTP
0
624
624
3,666
3,666
219
The Energy Authority
BPAT
NWMT
BPAT.NWMT
MATL.NWMT
0
120
120
706
706
220
The Energy Authority
BPAT
NWMT
BPAT.NWMT
NWMT.SYSTEM
0
100
100
588
588
221
The Energy Authority
BPAT
PPW
BPAT.NWMT
BRDY
0
335
335
1,970
1,970
222
The Energy Authority
BPAT
PPW
BPAT.NWMT
YTP
0
470
470
2,764
2,764
223
The Energy Authority
BPAT
PPW
BPAT.NWMT
YTP
0
1,200
1,200
7,050
7,050
224
The Energy Authority
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
2,299
2,299
13,518
13,518
225
The Energy Authority
NWMT
PPW
COLSTRIP
BRDY
0
47
47
276
276
226
The Energy Authority
PPW
BPAT
BRDY
BPAT.NWMT
0
105
105
617
617
227
The Energy Authority
PPW
BPAT
YTP
BPAT.NWMT
0
7,287
7,287
42,848
42,848
228
The Energy Authority
PPW
BPAT
YTP
BPAT.NWMT
0
336
336
1,974
1,974
229
The Energy Authority
WAPA
BPAT
CROSSOVER
BPAT.NWMT
0
3,806
3,806
22,379
22,379
230
Transalta Energy Marketing (US) Inc.
BPAT
PPW
BPAT.NWMT
BRDY
0
440
440
2,587
2,587
231
Transalta Energy Marketing (US) Inc.
BPAT
PPW
BPAT.NWMT
JEFF
0
16
16
94
94
232
Transalta Energy Marketing (US) Inc.
BPAT
PPW
BPAT.NWMT
YTP
0
476
476
2,799
2,799
233
Transalta Energy Marketing (US) Inc.
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
5,679
5,679
33,393
33,393
234
Transalta Energy Marketing (US) Inc.
PPW
BPAT
YTP
BPAT.NWMT
0
1,081
1,081
6,356
6,356
235
Transalta Energy Marketing (US) Inc.
PPW
WAPA
YTP
CROSSOVER
0
26
26
153
153
236
Transalta Energy Marketing (US) Inc.
WAPA
BPAT
CROSSOVER
BPAT.NWMT
0
8,019
8,019
47,152
47,152
237
Transalta Energy Marketing (US) Inc.
WAPA
PPW
CROSSOVER
BRDY
0
150
150
882
882
238
Western Area Power Administration
BPAT
WAPA
BPAT.NWMT
CROSSOVER
0
4,800
4,800
28,224
28,224
239
Western Area Power Administration
NWMT
WAPA
CANYONFERRY
CROSSOVER
0
63,606
63,606
374,003
374,003
240
Western Area Power Administration
WAPA
NWMT
GREATFALLS
NWMT.SYSTEM
0
4,318
4,318
25,650
25,650
241
Western Area Power Administration
WAPA
WAPA
CROSSOVER
GREATFALLS
0
25,315
25,315
149,625
149,625
242
Western Area Power Administration
WAPA
WAPA
GREATFALLS
CROSSOVER
0
64,760
64,760
384,750
384,750
243
SOUTH DAKOTA
244
BRYANT, CITY OF
WAPA
BRYANT
HURON 115 KV BUS
BRYANT 25 KV
1,249
1,249
5,960
5,960
245
GROTON, CITY OF
WAPA
GROTON
HURON 115 KV BUS
GROTON 69 KV
5,250
5,250
205
205
246
LANGFORD, CITY OF
WAPA
LANGFORD
HURON 115 KV BUS
LANGFORD 12.5 KV
886
886
3,930
3,930
247
Southwest Power Pool (SPP)
SPP
Various
Various
Various
(a)
53,061
53,061
248
Southwest Power Pool (SPP)
SPP
Various
Various
Various
(b)
16,449
16,449
249
Southwest Power Pool (SPP)
SPP
Various
Various
Various
(c)
1,629,156
1,629,156
250
Rounding
2
2
2
4
2
35 TOTAL
1,066
2,724,673
2,724,673
8,611,229
7,066,036
1,698,666
17,375,931


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
FOOTNOTE DATA

(a) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Firm and Non-Firm Point to Point Transmission Service
(b) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Non-Firm Point to Point Transmission Service
(c) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Network Integration Transmission Service

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
TRANSMISSION OF ELECTRICITY BY ISO/RTOs
  1. Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a).
  3. In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  4. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided.
  5. In column (d) report the revenue amounts as shown on bills or vouchers.
  6. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.
Payment Received by (Transmission Owner Name)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Total Revenue by Rate Schedule or Tariff
(d)
Total Revenue
(e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40
TOTAL


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
  1. Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter.
  2. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported.
  3. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
    FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications.
  4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service.
  5. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  6. Enter ""TOTAL"" in column (a) as the last line.
  7. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.
NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
TransmissionOfElectricityByOthersEnergyReceived
MegaWatt Hours Received
(c)
TransmissionOfElectricityByOthersEnergyDelivered
MegaWatt Hours Delivered
(d)
DemandChargesTransmissionOfElectricityByOthers
Demand Charges ($)
(e)
EnergyChargesTransmissionOfElectricityByOthers
Energy Charges ($)
(f)
OtherChargesTransmissionOfElectricityByOthers
Other Charges ($)
(g)
ChargesForTransmissionOfElectricityByOthers
Total Cost of Transmission ($)
(h)
1
MONTANA
2
Vigilante Elec. Coop
7,614
7,614
13,562
13,562
3
Bonneville Power Admin
(a)
913,773
913,773
4
Sun River Elect Coop
4,120
4,120
22,662
22,662
5
Southwester Power Pool (MT)
29,900
29,900
448,538
448,538
6
Supply:
7
Avista
113
113
994
994
8
Bonneville Power Admin
111,310
111,310
335,550
335,550
9
Seattle City Light
1,890
1,890
2,015
2,015
10
SOUTH DAKOTA
11
East River
496
496
12
West Central Elect COOP
2,441
2,441
13
Southwest Power Pool (SD)
5,591,075
5,591,075
TOTAL
154,947
154,947
6,078,774
338,559
913,773
7,331,106


FOOTNOTE DATA

(a) Concept: OtherChargesTransmissionOfElectricityByOthers
Monthly system usage fee.

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
Deprec, Depl and Amort of Elec Plant (403,403.1,404,and 405) (except Amortization of Acquisition Adjustments)
  1. Report the year to date amounts of depreciation expense, asset retirement cost depreciation, depletion and amortization, except amortization of acquisition adjustments for the accounts indicated and classified according to the plant functional groups described.
Line No.
FunctionalClassificationAxis
Functional Classification
(a)
DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments
Depreciation Expense (Account 403)
(b)
DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments
Depreciation Expense for Asset Retirement Costs (Account 403.1)
(c)
AmortizationOfLimitedTermPlantOrProperty
Amortization of Limited Term Electric Plant (Account 404)
(d)
AmortizationOfOtherElectricPlant
Amortization of Other Electric Plant (Acc 405)
(e)
DepreciationAndAmortization
Total
(f)
1
Intangible Plant
385,227
385,227
2
Steam Production Plant
1,860,438
1,860,438
3
Nuclear Production Plant
4
Hydraulic Production Plant-Conventional
2,530,893
2,530,893
5
Hydraulic Production Plant-Pumped Storage
6
Other Production Plant
4,430,657
884
4,431,541
7
Transmission Plant
6,940,299
125,724
7,066,023
8
Distribution Plant
15,024,702
6,345
15,018,357
9
General Plant
2,708,242
2,708,242
10
Common Plant-Electric
1,328,020
1,260,257
2,588,277
11
TOTAL
34,823,251
1,765,747
36,588,998


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
  1. The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.
Description of Item(s)
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1 Energy
2 Net Purchases (Account 555)
29,488,892
2.1 Net Purchases (Account 555.1)
3 Net Sales (Account 447)
26,809,262
4 Transmission Rights
5 Ancillary Services
24,860
6 Other Items (list separately)
7
Day Ahead & Real Time Admin
87,010
8
Market Monitoring & Compliance
12,430
46 TOTAL
56,422,454


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
Monthly Peak Loads and Energy Output
  1. Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system.
  2. Report in column (b) by month the system’s output in Megawatt hours for each month.
  3. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales.
  4. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system.
  5. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.
MonthAxis
Month
(a)
Total Monthly Energy (MWH)
(b)
Monthly Non-Requirements Sales for Resale & Associated Losses
(c)
MonthlyPeakLoad
Monthly Peak Megawatts (See Instr. 4)
(d)
DayOfMonthlyPeak
Monthly Peak Day of Month
(e)
HourOfMonthlyPeak
Monthly Peak Hour
(f)
NAME OF SYSTEM: Montana Operations
1
January
2
February
3
March
4
Total for Quarter 1
5
April
6
May
7
June
8
Total for Quarter 2
9
July
10
August
11
September
12
Total for Quarter 3
41
Total
NAME OF SYSTEM: South Dakota Operations
1
January
2
February
3
March
4
Total for Quarter 1
5
April
6
May
7
June
8
Total for Quarter 2
9
July
10
August
11
September
12
Total for Quarter 3
41
Total


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
FOOTNOTE DATA

(a) Concept: EnergyActivity
MONTANA OPERATIONS

Line
No
Month Total Monthly Energy (MWH) Monthly Non-Requirements Sales for Resale & Associated Losses Monthly Peak Megawatts Monthly Peak Day of Month Monthly Peak Hour
(a) (b) (c ) (d) (e) (f)
1 January 787,896  72,612  2,037  5 19
2 February 676,659  113,763  2,072  23 8
3 March 714,044  94,680  1,893  10 8
4 Total for Quarter 2,178,599  281,055 


SOUTH DAKOTA OPERATIONS

Line
No
Month Total Monthly Energy (MWH) Monthly Non-Requirements Sales for Resale & Associated Losses Monthly Peak Megawatts Monthly Peak Day of Month Monthly Peak Hour
(a) (b) (c ) (d) (e) (f)
1 January 150,175  —  300  6 8
2 February 185,149  —  288  22 10
3 March 144,795  —  228  11 9
4 Total for Quarter 480,119  — 

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
  1. Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Firm Network Service for Self
(e)
Firm Network Service for Others
(f)
Long-Term Firm Point-to-point Reservations
(g)
Other Long-Term Firm Service
(h)
Short-Term Firm Point-to-point Reservation
(i)
Other Service
(j)
NAME OF SYSTEM: Montana Operations
1
January
1,947
5
19
1,046
707
78
12
7,405
2
February
1,982
23
8
1,042
749
78
12
3,969
3
March
1,803
10
8
1,052
704
78
12
2,634
4
Total for Quarter 1
3,140
2,160
234
36
14,008
5
April
6
May
7
June
8
Total for Quarter 2
0
0
0
0
0
9
July
10
August
11
September
12
Total for Quarter 3
0
0
0
0
0
13
October
14
November
15
December
16
Total for Quarter 4
0
0
0
0
0
17
Total
3,140
2,160
234
36
14,008
0
NAME OF SYSTEM: South Dakota Operations
1
January
2
February
3
March
4
Total for Quarter 1
5
April
6
May
7
June
8
Total for Quarter 2
9
July
10
August
11
September
12
Total for Quarter 3
13
October
14
November
15
December
16
Total for Quarter 4
17
Total


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

03/31/2022
Year/Period of Report

End of:
2022
/
Q1
Monthly ISO/RTO Transmission System Peak Load
  1. Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f).
  5. Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Import into ISO/RTO
(e)
Exports from ISO/RTO
(f)
Through and Out Service
(g)
Network Service Usage
(h)
Point-to-Point Service Usage
(i)
Total Usage
(j)
NAME OF SYSTEM: South Dakota Operations
1
January
300
6
8
315
15
330
2
February
288
22
10
302
14
316
3
March
228
11
9
240
12
252
4
Total for Quarter 1
857
41
898
5
April
0
6
May
0
7
June
0
8
Total for Quarter 2
0
0
0
9
July
0
10
August
0
11
September
0
12
Total for Quarter 3
0
0
0
13
October
0
14
November
0
15
December
0
16
Total for Quarter 4
17
Total Year to Date/Year
857
41
898