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AVA NWMT NF MONTANA OATT AVAT.NWMT MATL.NWMT 2022-01-012022-09-30 C001789 REC Silicon Company Morgan Stanley REC Silicon Company FNO Montana OATT Hardin  Butte, MT 2022-01-012022-09-30 C001789 Bonneville Power Administration BPA  Bonneville Power Administration FNO Montana OATT BPAT.NWMT    Various in Montana 2022-01-012022-09-30 C001789 Montana Operationsferc:FebruaryMember 2022-01-012022-09-30 C001789 ferc:Quarter3Member South Dakota Operations 2022-01-012022-09-30 C001789 Portland General Electric Company NWMT BPAT NF MONTANA OATT COLSTRIP BPAT.NWMT 2022-01-012022-09-30 C001789 Montana Consumer Counsel Tax (Montana) - Docket 2018.10.67 - Order 7637 2022-01-012022-09-30 C001789 MONTANA 2022-01-012022-09-30 C001789 Portland General Electric Company NWMT PPW NF MONTANA OATT COLSTRIP JEFF 2022-01-012022-09-30 C001789 Montana Operationsferc:Quarter1Member 2022-01-012022-09-30 C001789 Bonneville Power Administration BPAT NWMT NF MONTANA OATT BPAT.NWMT NWMT.SYSTEM 2022-01-012022-09-30 C001789 Transalta Energy Marketing (US) Inc. WAPA BPAT SFP MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 BRYANT, CITY OF WAPA BRYANT LFP VOL 2 HURON 115 KV BUS BRYANT 25 KV 2022-01-012022-09-30 C001789 Mercuria Energy America, LLC PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Line of Credit (Repayments) Borrowings, Net 2022-01-012022-09-30 C001789 Barretts Minerals, Inc. Energy Keepers inc. Barretts Minerals, Inc. FNO Montana OATT Kerr Dillon, MT 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT PACE NF MONTANA OATT KERR BRDY 2022-01-012022-09-30 C001789 Western Area Power Administration WAPA Malmstrom Air Force Base FNO Montana OATT Fort Peck West Great Falls, MT 2022-01-012022-09-30 C001789 Flow-through Income Taxes (South Dakota) 2022-09-30 C001789 EDF Trading North America, LLC NWMT NWMT NF MONTANA OATT COLSTRIP NWMT.SYSTEM 2022-01-012022-09-30 C001789 PacifiCorp NWMT PPW SFP MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 Shell Energy North America WAPA PPW NF MONTANA OATT CROSSOVER YTP 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. BPAT NWMT NF MONTANA OATT BPAT.NWMT NWMT.SYSTEM 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative NWMT PPW NF MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 ferc:AugustMember Montana Operations 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. PPW WAPA NF MONTANA OATT YTP CROSSOVER 2022-01-012022-09-30 C001789 2022-01-012022-03-31 C001789 Macquarie Energy, LLC AVA PPW SFP MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 BPA Residential Exchange Program (Montana) - Docket 2018.8.49 Order 7630; Annual Amortization 2022-01-012022-09-30 C001789 Shell Energy North America PPW AVA SFP MONTANA OATT YTP AVAT.NWMT 2022-01-012022-09-30 C001789 MAG Energy Solutions NWMT BPAT NF MONTANA OATT MATL.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 Day Ahead & Real Time Admin 2022-01-012022-09-30 C001789 Study of the Costs & Benefits of Customer Generators (Montana) 2022-01-012022-09-30 C001789 ferc:JanuaryMember South Dakota Operations 2022-01-012022-09-30 C001789 FAS 106 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-01-012022-09-30 C001789 Black Hills Power Inc. NWMT PPW NF MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 Ash Grove Cement Energy Keepers Inc. Ash Grove Cement FNO Montana OATT Kerr Clancy, MT 2022-01-012022-09-30 C001789 Powerex Corporation BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. BPAT PPW NF MONTANA OATT BPAT.NWMT BRDY 2022-01-012022-09-30 C001789 EDF Trading North America, LLC NWMT BPAT NF MONTANA OATT CANYONFERRY BPAT.NWMT 2022-01-012022-09-30 C001789 ferc:AprilMember Montana Operations 2022-01-012022-09-30 C001789 FAS 112 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-09-30 C001789 Morgan Stanley Capital Group, Inc. BPAT PPW SFP MONTANA OATT BPAT.NWMT JEFF 2022-01-012022-09-30 C001789 Shell Energy North America BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Avista Corporation AVA AVA SFP MONTANA OATT COLSTRIP AVAT.NWMT 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (South Dakota) 2022-09-30 C001789 Calumet Refining, LLC Talen Energy Calumet Montana Refining Company, Inc. FNO Montana OATT Colstrip Great Falls, MT 2022-01-012022-09-30 C001789 Dynasty Power Inc. PPW BPAT SFP MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Dynasty Power Inc. AVA WAPA NF MONTANA OATT AVAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 ferc:JuneMember South Dakota Operations 2022-01-012022-09-30 C001789 Macquarie Energy, LLC PPW BPAT SFP MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 ferc:OtherUtilityMember 2022-09-30 C001789 Basin Electric Power Cooperative NWMT WAPA NF MONTANA OATT COLSTRIP CROSSOVER 2022-01-012022-09-30 C001789 Flow-through Income Taxes (Montana) 2022-07-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT AVA NF MONTANA OATT KERR AVAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. BPAT NWMT SFP MONTANA OATT BPAT.NWMT MATL.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. WAUW NWMT NF MONTANA OATT GREATFALLS MATL.NWMT 2022-01-012022-09-30 C001789 Flow-through Income Taxes (Montana) 2022-01-012022-09-30 C001789 Pension Plan (South Dakota) 2022-06-30 C001789 EDF Trading North America, LLC BPAT NWMT NF MONTANA OATT BPAT.NWMT GTFALLSNWMT 2022-01-012022-09-30 C001789 Energy Keepers Inc. AVA BPAT NF MONTANA OATT AVAT.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 Market Monitoring & Compliance 2022-01-012022-03-31 C001789 Pension Plan (Montana) 2022-07-012022-09-30 C001789 CTC QF Over/Under Collections (Montana) - Docket 97.9.90 and Docket 2001.1.15; Annual Amortization 2022-06-30 C001789 Morgan Stanley Capital Group, Inc. GWA NWMT NF MONTANA OATT GLWND2 NWMT.SYSTEM 2022-01-012022-09-30 C001789 Manufactured Gas Plants (South Dakota) - Docket NG 11-003 2022-01-012022-09-30 C001789 2022-01-012022-06-30 C001789 2021-12-31 C001789 Town of Philipsburg Town of Philipsburg Town of Philipsburg FNO Montana OATT Philipsburg Substation Philipsburg, MT 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT BPAT NF MONTANA OATT KERR BPAT.NWMT 2022-01-012022-09-30 C001789 Bonneville Power Admin OLF 2022-01-012022-09-30 C001789 2022-06-30 C001789 Transalta Energy Marketing (US) Inc. NWMT BPAT NF MONTANA OATT MATL.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 EDF Trading North America, LLC NWMT BPAT NF MONTANA OATT COLSTRIP BPAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT NF MONTANA OATT HARDIN MATL.NWMT 2022-01-012022-09-30 C001789 MONTANA POINT-TO-POINT      2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. AVA AVA NF MONTANA OATT COLSTRIP AVAT.NWMT 2022-01-012022-09-30 C001789 Great Falls Public Schools Energy Keepers Inc. Great Falls Public Schools FNO Montana OATT Kerr Great Falls, MT 2022-01-012022-09-30 C001789 Shell Energy North America NWMT AVA NF MONTANA OATT TFALLS AVAT.NWMT 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative PPW PPW NF MONTANA OATT BRDY MLCK 2022-01-012022-09-30 C001789 Montana Consumer Counsel Tax (Montana) - Docket 2018.10.67 - Order 7637 2022-07-012022-09-30 C001789 CP Energy Marketing (US) Inc. NWMT PACE NF MONTANA OATT MATL.NWMT YTP 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT BPAT SFP MONTANA OATT COLSTRIP BPAT.NWMT 2022-01-012022-09-30 C001789 Guzman Energy, LLC NWMT PPW NF MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 Asset Retirement Obligation (Montana) 2022-06-30 C001789 Rainbow Electric Marketing Corp. NWMT WAUW NF MONTANA OATT NWMTIMBALANC CROSSOVER 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. NWMT PPW NF MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 ScheduleRegionalTransmissionServiceRevenuesAbstract 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative PPW WAPA NF MONTANA OATT BRDY CROSSOVER 2022-01-012022-09-30 C001789 The Energy Authority PPW PPW NF MONTANA OATT YTP BRDY 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. BPAT WAPA NF MONTANA OATT BPAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT BPAT NF MONTANA OATT COLSTRIP BPAT.NWMT 2022-01-012022-09-30 C001789 Other Noncash Charges to Income, Net 2022-01-012022-09-30 C001789 Macquarie Energy, LLC NWMT BPAT NF MONTANA OATT HOLTER BPAT.NWMT 2022-01-012022-09-30 C001789 Natural Gas Transmission Verification Program (Montana) - Docket D2016.11.88 2022-06-30 C001789 Field Inventory (South Dakota) - Docket EL 14-106 2022-01-012022-09-30 C001789 ferc:TransmissionStudiesMember 2022-01-012022-09-30 C001789 ferc:SteamProductionPlantMemberferc:ElectricUtilityMember 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT GWA NF MONTANA OATT MATL.NWMT GLWND2 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (Montana) 2022-07-012022-09-30 C001789 City of Great Falls Energy Keepers Inc. City of Great Falls FNO Montana OATT Kerr Various in Montana 2022-01-012022-09-30 C001789 Seattle City Light NF 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (Montana) 2022-09-30 C001789 Current Ad Valorem True-Up (South Dakota) - Docket GE98-001 2022-07-012022-09-30 C001789 Idaho Power Company PPW IPCO SFP MONTANA OATT JEFF TNDY 2022-01-012022-09-30 C001789 Transalta Energy Marketing (US) Inc. BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Shell Energy North America PPW AVA NF MONTANA OATT YTP AVAT.NWMT 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative NWMT NWMT NF MONTANA OATT COLSTRIP NWMT.SYSTEM 2022-01-012022-09-30 C001789 ferc:DistributionPlantMemberferc:ElectricUtilityMember 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. BPAT GWA NF MONTANA OATT BPAT.NWMT GLWND2 2022-01-012022-09-30 C001789 BPA Residential Exchange Program (Montana) - Docket 2018.8.49 Order 7630; Annual Amortization 2022-06-30 C001789 Montana Operationsferc:JuneMember 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA NWMT NF MONTANA OATT GLWND1 MATL.NWMT 2022-01-012022-09-30 C001789 Montana Public Service Commission (Montana) - Docket 2017.9.78 - Order 7568 2022-09-30 C001789 Energy Keepers Inc. NWMT PACE NF MONTANA OATT KERR YTP 2022-01-012022-09-30 C001789 Natural Gas Regulatory Deferrals (Montana) 2022-06-30 C001789 Aberdeen Manufactured Gas Plant (South Dakota) - Docket NG 11-003 2022-01-012022-09-30 C001789 ferc:CommonUtilityMember 2022-09-30 C001789 FAC Studiesferc:GenerationStudiesMember 2022-01-012022-09-30 C001789 Line Interconnection Studies 2022-01-012022-09-30 C001789 Natural Gas Regulatory Deferrals (Montana) 2022-01-012022-09-30 C001789 The Energy Authority BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Montana Public Service Commission Consumer Counsel Taxes (Montana) - Dockets 2017.9.78 and 2018.10.67 2022-07-012022-09-30 C001789 CTC QF Over/Under Collections (Montana) - Docket 97.9.90 and Docket 2001.1.15; Annual Amortization 2022-07-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT NF MONTANA OATT COLSTRIP MATL.NWMT 2022-01-012022-09-30 C001789 Macquarie Energy, LLC WAPA BPAT NF MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA BPAT SFP MONTANA OATT GLWND1 BPAT.NWMT 2022-01-012022-09-30 C001789 BPA Residential Exchange Program (Montana) - Docket 2018.8.49 Order 7630; Annual Amortization 2022-07-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. WAPA AVA NF MONTANA OATT GREATFALLS AVAT.NWMT 2022-01-012022-09-30 C001789 Energy Keepers Inc. PPW NWMT SFP MONTANA OATT YTP GTFALLSNWMT 2022-01-012022-09-30 C001789 Mercuria Energy America, LLC AVA PPW SFP MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 Amortization of 2022-01-012022-09-30 C001789 Macquarie Energy, LLC NWMT BPAT SFP MONTANA OATT HOLTER BPAT.NWMT 2022-01-012022-09-30 C001789 Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization 2022-01-012022-09-30 C001789 ferc:OctoberMember South Dakota Operations 2022-01-012022-09-30 C001789 The Energy Authority WAPA BPAT NF MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative Basin Electric & WAPA Basin Electric Power Cooperative FNO Montana OATT Crossover  Various NWMT & WAUW 2022-01-012022-09-30 C001789 Southwest Power Pool (SD) FNS 2022-01-012022-09-30 C001789 Aspen Air U.S., LLC Talen Energy Aspen Air Corporation FNO Montana OATT Colstrip  Billings, MT 2022-01-012022-09-30 C001789 ferc:OtherProductionPlantMemberferc:ElectricUtilityMember 2022-01-012022-09-30 C001789 ferc:HydraulicProductionPlantConventionalMemberferc:ElectricUtilityMember 2022-01-012022-09-30 C001789 Bonneville Power Administration PPW NWMT NF MONTANA OATT BRDY NWMT.SYSTEM 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA WAPA NF MONTANA OATT GLWND1 CROSSOVER 2022-01-012022-09-30 C001789 Macquarie Energy, LLC NWMT PPW NF MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 Southwest Power Pool (SPP) SPP Various LFP SCH 11 Various Various 2022-01-012022-09-30 C001789 The Energy Authority AVA BPAT NF MONTANA OATT AVAT.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 ferc:OtherUtilityMember 2021-01-012021-09-30 C001789 ferc:GasUtilityMember 2021-01-012021-09-30 C001789 Natural Gas Transmission Verification Program (Montana) - Docket D2016.11.88 2022-07-012022-09-30 C001789 Dynasty Power Inc. PPW PPW NF MONTANA OATT YTP BRDY 2022-01-012022-09-30 C001789 CP Energy Marketing (US) Inc. NWMT BPAT NF MONTANA OATT MATL.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 CTC QF Over/Under Collections (Montana) - Docket 97.9.90 and Docket 2001.1.15; Annual Amortization 2022-09-30 C001789 Macquarie Energy, LLC WAPA PPW NF MONTANA OATT CROSSOVER YTP 2022-01-012022-09-30 C001789 Powerex Corporation AVA WAPA NF MONTANA OATT AVAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Avista Corporation NWMT AVA NF MONTANA OATT COLSTRIP AVAT.NWMT 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (South Dakota) 2022-07-012022-09-30 C001789 Energy Keepers Inc. NWMT PACE SFP MONTANA OATT KERR YTP 2022-01-012022-09-30 C001789 Shell Energy North America NWMT AVA NF MONTANA OATT HOLTER AVAT.NWMT 2022-01-012022-09-30 C001789 CP Energy Marketing (US) Inc. WAPA BPAT NF MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 ferc:NovemberMember South Dakota Operations 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (Montana) 2022-07-012022-09-30 C001789 Pension Plan (South Dakota) 2022-09-30 C001789 Current Ad Valorem True-Up (South Dakota) - Docket GE98-001 2022-09-30 C001789 Flow-through Income Taxes (Montana) 2022-06-30 C001789 ferc:Quarter1Member South Dakota Operations 2022-01-012022-09-30 C001789 SOUTH DAKOTA      2022-01-012022-09-30 C001789 Other Noncash Charges to Income, Net 2021-01-012021-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT AVA SFP MONTANA OATT MATL.NWMT AVAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA PPW NF MONTANA OATT GLWND1 BRDY 2022-01-012022-09-30 C001789 SIS Studiesferc:TransmissionStudiesMember 2022-01-012022-09-30 C001789 Field Inventory (South Dakota) - Docket EL 14-106 2022-06-30 C001789 Macquarie Energy, LLC AVA PPW NF MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. WAPA PPW NF MONTANA OATT CROSSOVER YTP 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT BPAT NF MONTANA OATT JUDITHGAP BPAT.NWMT 2022-01-012022-09-30 C001789 Other 2022-01-012022-09-30 C001789 2022-01-012022-09-30 C001789 Beartooth Electric Cooperative, Inc. WAPA Beartooth Electric Cooperative, Inc. FNO Montana OATT Fort Peck Various in Montana 2022-01-012022-09-30 C001789 ferc:OtherUtility2Member 2022-09-30 C001789 Montana State University - Bozeman WAPA Montana State University - Bozeman FNO Montana OATT Fort Peck West Great Falls, MT 2022-01-012022-09-30 C001789 Avista Corporation AVA AVA NF MONTANA OATT COLSTRIP AVAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA AVA NF MONTANA OATT GLWND2 AVAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. AVA GWA NF MONTANA OATT AVAT.NWMT GLWND1 2022-01-012022-09-30 C001789 Energy Keepers Inc. PPW BPAT SFP MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 ferc:GasUtilityMember 2022-09-30 C001789 Study of the Costs & Benefits of Customer Generators (Montana) 2022-06-30 C001789 Deferred Gas Storage Sales (Montana) - Docket D2001.1.1; Amortization 2001 - 2039 2022-07-012022-09-30 C001789 EDF Trading North America, LLC NWMT PPW NF MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT PACE LFP MONTANA OATT KERR BRDY 2022-01-012022-09-30 C001789 SIS Studiesferc:GenerationStudiesMember 2022-01-012022-09-30 C001789 Suiza Dairy Group, LLC Talen Energy Suiza Dairy Group, LLC FNO Montana OATT Colstrip Various in Montana 2022-01-012022-09-30 C001789 ferc:MarchMember South Dakota Operations 2022-01-012022-09-30 C001789 Western Area Power Administration WAPA WAPA SFP MONTANA OATT CROSSOVER GREATFALLS 2022-01-012022-09-30 C001789 ferc:SeptemberMember South Dakota Operations 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (South Dakota) 2022-07-012022-09-30 C001789 TEC Energy Inc. NWMT BPAT NF MONTANA OATT MATL.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 ferc:AprilMember South Dakota Operations 2022-01-012022-09-30 C001789 (Less) (449.1) Provision for Rate Refunds 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. BPAT GWA NF MONTANA OATT BPAT.NWMT GLWND1 2022-01-012022-09-30 C001789 Big Horn County Electric Coop. Inc. WAPA Big Horn County Electric Coop. Inc. FNO Montana OATT Various & Great Falls  Various in Montana 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. WAPA AVA NF MONTANA OATT CROSSOVER AVAT.NWMT 2022-01-012022-09-30 C001789 Brookfield Renewable Trading and Marketing LP PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Dynasty Power Inc. BPAT WAPA NF MONTANA OATT BPAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (South Dakota) 2022-01-012022-09-30 C001789 Deferred Gas Storage Sales (Montana) - Docket D2001.1.1; Amortization 2001 - 2039 2022-09-30 C001789 Benefis Health Systems Energy Keepers inc. Benefis Health Systems FNO Montana OATT Kerr Various in Montana 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT AVA NF MONTANA OATT MATL.NWMT AVAT.NWMT 2022-01-012022-09-30 C001789 Avista NF 2022-01-012022-09-30 C001789 Montana Consumer Counsel Tax (Montana) - Docket 2018.10.67 - Order 7637 2022-09-30 C001789 Energy Keepers Inc. NWMT AVA NF MONTANA OATT KERR AVAT.NWMT 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative WAPA NWMT SFP MONTANA OATT CROSSOVER NWMT.SYSTEM 2022-01-012022-09-30 C001789 Basin Creek Capital Lease (Montana) 2022-01-012022-09-30 C001789 Montana Public Service Commission (Montana) - Docket 2017.9.78 - Order 7568 2022-06-30 C001789 FEA Studies 2022-01-012022-09-30 C001789 FAS 106 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-06-30 C001789 Bonneville Power Administration BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Macquarie Energy, LLC PPW AVA NF MONTANA OATT YTP AVAT.NWMT 2022-01-012022-09-30 C001789 Market Monitoring & Compliance 2022-01-012022-06-30 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT SFP MONTANA OATT COLSTRIP BPAT.NWMT 2022-01-012022-09-30 C001789 Dynasty Power Inc. AVA PPW NF MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 Bonneville Power Administration AVA NWMT NF MONTANA OATT AVAT.NWMT NWMT.SYSTEM 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. BPAT NWMT SFP MONTANA OATT BPAT.NWMT COLSTRIP 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA PPW NF MONTANA OATT GLWND1 JEFF 2022-01-012022-09-30 C001789 EDF Trading North America, LLC NWMT NWMT NF MONTANA OATT BASINCREEK NWMT.SYSTEM 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT BPAT NF MONTANA OATT HOLTER BPAT.NWMT 2022-01-012022-09-30 C001789 Shell Energy North America WAPA AVA NF MONTANA OATT CROSSOVER AVAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA BPAT NF MONTANA OATT GLWND2 BPAT.NWMT 2022-01-012022-09-30 C001789 Manufactured Gas Plants (South Dakota) - Docket NG 11-003 2022-07-012022-09-30 C001789 Powerex Corporation PPW WAPA NF MONTANA OATT YTP CROSSOVER 2022-01-012022-09-30 C001789 GROTON, CITY OF WAPA GROTON LFP VOL 2 HURON 115 KV BUS GROTON 69 KV 2022-01-012022-09-30 C001789 CTC QF Over/Under Collections (Montana) - Docket 97.9.90 and Docket 2001.1.15; Annual Amortization 2022-01-012022-09-30 C001789 Shell Energy North America BPAT NWMT NF MONTANA OATT BPAT.NWMT GTFALLSNWMT 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (South Dakota) 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative WAPA PPW NF MONTANA OATT CROSSOVER YTP 2022-01-012022-09-30 C001789 Aberdeen Manufactured Gas Plant (South Dakota) - Docket NG 11-003 2022-07-012022-09-30 C001789 Montana Operationsferc:MarchMember 2022-01-012022-09-30 C001789 ferc:ElectricUtilityMember 2022-09-30 C001789 FAS 112 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-06-30 C001789 Asset Retirement Obligation (Montana) 2022-07-012022-09-30 C001789 Study of the Costs & Benefits of Customer Generators (Montana) 2022-07-012022-09-30 C001789 ferc:ElectricUtilityMember 2022-01-012022-09-30 C001789 Black Hills Power Inc. AVA PPW NF MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 CP Energy Marketing (US) Inc. PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Transalta Energy Marketing (US) Inc. PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Southwest Power Pool (SPP) SPP Various LFP SCH 7 Various Various 2022-01-012022-09-30 C001789 Basin Creek Capital Lease (Montana) 2022-06-30 C001789 Basin Creek Capital Lease (Montana) 2022-09-30 C001789 Shell Energy North America NWMT AVA SFP MONTANA OATT HOLTER AVAT.NWMT 2022-01-012022-09-30 C001789 Shell Energy North America WAPA AVA SFP MONTANA OATT CROSSOVER AVAT.NWMT 2022-01-012022-09-30 C001789 Macquarie Energy, LLC NWMT WAPA NF MONTANA OATT COLSTRIP CROSSOVER 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. BPAT NWMT NF MONTANA OATT BPAT.NWMT MATL.NWMT 2022-01-012022-09-30 C001789 Montana Operationsferc:JanuaryMember 2022-01-012022-09-30 C001789 Macquarie Energy, LLC PPW AVA SFP MONTANA OATT YTP AVAT.NWMT 2022-01-012022-09-30 C001789 MONTANA CHOICE TRANSMISSION      2022-01-012022-09-30 C001789 EDF Trading North America, LLC NWMT AVA NF MONTANA OATT COLSTRIP AVAT.NWMT 2022-01-012022-09-30 C001789 The Energy Authority AVA WAPA NF MONTANA OATT AVAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Debt Financing Costs 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. AVA PPW NF MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA GWA SFP MONTANA OATT GLWND1 GLWND2 2022-01-012022-09-30 C001789 EDF Trading North America, LLC NWMT AVA SFP MONTANA OATT COLSTRIP AVAT.NWMT 2022-01-012022-09-30 C001789 Atlas Power, LLC Portland General Electric Atlas Power, LLC FNO Montana OATT Colstrip Butte, MT 2022-01-012022-09-30 C001789 Montana Operationsferc:JulyMember 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative PPW WAPA NF MONTANA OATT BRDY GREATFALLS 2022-01-012022-09-30 C001789 Shell Energy North America BPAT PPW NF MONTANA OATT BPAT.NWMT BRDY 2022-01-012022-09-30 C001789 Shell Energy North America PPW BPAT SFP MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 EDF Trading North America, LLC BPAT NWMT NF MONTANA OATT BPAT.NWMT COLSTRIP 2022-01-012022-09-30 C001789 Guzman Energy, LLC AVA PPW SFP MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. PPW BPAT SFP MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 FAS 106 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-09-30 C001789 Tax Cut Jobs Act Deferral (South Dakota) - Docket NG-0095 and GE17-003 2022-01-012022-09-30 C001789 2021-01-012021-09-30 C001789 Powerex Corporation PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Macquarie Energy, LLC NWMT AVA NF MONTANA OATT HOLTER AVAT.NWMT 2022-01-012022-09-30 C001789 Investment in Equity Securities 2021-01-012021-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT GWA NF MONTANA OATT MATL.NWMT GLWND1 2022-01-012022-09-30 C001789 Powerex Corporation BPAT PPW LFP MONTANA OATT BPAT.NWMT JEFF 2022-01-012022-09-30 C001789 FAC Studies 2022-01-012022-09-30 C001789 Brookfield Renewable Trading and Marketing LP BPAT WAPA NF MONTANA OATT BPAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Natural Gas Regulatory Deferrals (Montana) 2022-09-30 C001789 ferc:GenerationStudiesMember 2022-01-012022-09-30 C001789 Shell Energy North America BPAT WAPA NF MONTANA OATT BPAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Montana Public Service Commission Consumer Counsel Taxes (Montana) - Dockets 2017.9.78 and 2018.10.67 2022-06-30 C001789 Montana Consumer Counsel Tax (Montana) - Docket 2018.10.67 - Order 7637 2022-06-30 C001789 Tax Cut Jobs Act Deferral (South Dakota) - Docket NG-0095 and GE17-003 2022-06-30 C001789 Field Inventory (South Dakota) - Docket EL 14-106 2022-07-012022-09-30 C001789 EDF Trading North America, LLC BPAT NWMT NF MONTANA OATT BPAT.NWMT NWMT.SYSTEM 2022-01-012022-09-30 C001789 Southwest Power Pool (SPP) SPP Various FNS SCH 9 Various Various 2022-01-012022-09-30 C001789 Current Ad Valorem True-Up (South Dakota) - Docket GE98-001 2022-01-012022-09-30 C001789 Day Ahead & Real Time Admin 2022-01-012022-06-30 C001789 ferc:MayMember South Dakota Operations 2022-01-012022-09-30 C001789 Asset Retirement Obligation (South Dakota) 2022-09-30 C001789 Aberdeen Manufactured Gas Plant (South Dakota) - Docket NG 11-003 2022-09-30 C001789 Macquarie Energy, LLC AVA PPW NF MONTANA OATT AVAT.NWMT BRDY 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA NWMT SFP MONTANA OATT GLWND2 NWMT.SYSTEM 2022-01-012022-09-30 C001789 Line of Credit (Repayments) Borrowings, Net 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (Montana) 2022-06-30 C001789 Morgan Stanley Capital Group, Inc. GWA AVA NF MONTANA OATT GLWND1 AVAT.NWMT 2022-01-012022-09-30 C001789 Optional Studies 2022-01-012022-09-30 C001789 Compensated Absences (Montana) - Docket 97.11.219 2022-06-30 C001789 CP Energy Marketing (US) Inc. BPAT NWMT NF MONTANA OATT BPAT.NWMT MATL.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT SFP MONTANA OATT KERR MATL.NWMT 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (Montana) 2022-06-30 C001789 Western Area Power Administration WAPA Western Area Power Administration FNO Montana OATT Crossover Various NWMT & WAUW 2022-01-012022-09-30 C001789 Powerex Corporation WAPA BPAT NF MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT BPAT NF MONTANA OATT STILLWIND BPAT.NWMT 2022-01-012022-09-30 C001789 Macquarie Energy, LLC AVA WAPA NF MONTANA OATT AVAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. PPW AVA NF MONTANA OATT YTP AVAT.NWMT 2022-01-012022-09-30 C001789 Flow-through Income Taxes (South Dakota) 2022-06-30 C001789 Western Area Power Administration WAPA WAPA NF MONTANA OATT GREATFALLS CROSSOVER 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative Morgan Stanley, Talen & WAPA Basin Electric Power Cooperative FNO Montana OATT Various in Montana Various NWMT & WAUW 2022-01-012022-09-30 C001789 Energy Keepers Inc. AVA PPW SFP MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative PPW NWMT NF MONTANA OATT YTP NWMT.SYSTEM 2022-01-012022-09-30 C001789 ferc:GeneralPlantMemberferc:ElectricUtilityMember 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT NF MONTANA OATT HARDIN NWMT.SYSTEM 2022-01-012022-09-30 C001789 The Energy Authority PPW AVA NF MONTANA OATT YTP AVAT.NWMT 2022-01-012022-09-30 C001789 EDF Trading North America, LLC NWMT NWMT NF MONTANA OATT COLSTRIP COLSTRIP 2022-01-012022-09-30 C001789 Treasury Stock Activity 2021-01-012021-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT NF MONTANA OATT KERR BPAT.NWMT 2022-01-012022-09-30 C001789 Flow-through Income Taxes (South Dakota) 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. AVA PPW NF MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 Deferred Gas Storage Sales (Montana) - Docket D2001.1.1; Amortization 2001 - 2039 2022-01-012022-09-30 C001789 Shell Energy North America NWMT AVA SFP MONTANA OATT TFALLS AVAT.NWMT 2022-01-012022-09-30 C001789 The Energy Authority NWMT PACE NF MONTANA OATT TFALLS YTP 2022-01-012022-09-30 C001789 ferc:JulyMember South Dakota Operations 2022-01-012022-09-30 C001789 Natural Gas Regulatory Deferrals (Montana) 2022-07-012022-09-30 C001789 2021-07-012021-09-30 C001789 Morgan Stanley Capital Group, Inc. AVA GWA NF MONTANA OATT AVAT.NWMT GLWND2 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. WAPA BPAT NF MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 Unbilled Revenues (South Dakota) 2022-06-30 C001789 Basin Electric Power Cooperative NWMT PPW SFP MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 GCC Three Forks, LLC Energy Keepers Inc. GCC Three Forks, LLC FNO Montana OATT Kerr Three Forks, MT 2022-01-012022-09-30 C001789 CP Energy Marketing (US) Inc. WAPA PPW NF MONTANA OATT CROSSOVER JEFF 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative NWMT WAUW NF MONTANA OATT COLSTRIP GREATFALLS 2022-01-012022-09-30 C001789 ferc:CommonPlantElectricMemberferc:ElectricUtilityMember 2022-01-012022-09-30 C001789 The Energy Authority BPAT WAPA NF MONTANA OATT BPAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 ferc:TransmissionPlantMemberferc:ElectricUtilityMember 2022-01-012022-09-30 C001789 CHS, Inc. Morgan Stanley CHS, Inc. FNO Montana OATT MATL.NWMT Various in Montana 2022-01-012022-09-30 C001789 Phillips 66 Company Shell Energy Phillips 66 Company FNO Montana OATT BPAT.NWMT Various in Montana 2022-01-012022-09-30 C001789 Montana Operationsferc:MayMember 2022-01-012022-09-30 C001789 Cycle Power Partners, LLC NWMT PACE NF MONTANA OATT HORSESHOE BRDY 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. BPAT WAPA NF MONTANA OATT BPAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Guzman Energy, LLC PPW BPAT SFP MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 ferc:OtherUtility3Member 2022-09-30 C001789 Transalta Energy Marketing (US) Inc. BPAT WAPA NF MONTANA OATT BPAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT BPAT NF MONTANA OATT MATL.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 Rounding      2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT BPA NF MONTANA OATT BGI BPAT.NWMT 2022-01-012022-09-30 C001789 ferc:AugustMember South Dakota Operations 2022-01-012022-09-30 C001789 Asset Retirement Obligation (South Dakota) 2022-01-012022-09-30 C001789 Macquarie Energy, LLC NWMT BPAT NF MONTANA OATT TFALLS BPAT.NWMT 2022-01-012022-09-30 C001789 Flow-through Income Taxes (South Dakota) 2022-07-012022-09-30 C001789 Macquarie Energy, LLC NWMT AVA SFP MONTANA OATT CANYONFERRY AVAT.NWMT 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative AVA WAPA NF MONTANA OATT AVAT.NWMT GREATFALLS 2022-01-012022-09-30 C001789 Montana Public Service Commission (Montana) - Docket 2017.9.78 - Order 7568 2022-07-012022-09-30 C001789 Dynasty Power Inc. PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Vitol Inc. AVA PPW NF MONTANA OATT AVAT.NWMT BRDY 2022-01-012022-09-30 C001789 Common Stock Dividend 2022-01-012022-09-30 C001789 Talen Montana, LLC Avista Energy Colstrip Steam Electric Station FNO Montana OATT Colstrip Nichols Pump Sub 2022-01-012022-09-30 C001789 Montana Public Service Commission Consumer Counsel Taxes (Montana) - Dockets 2017.9.78 and 2018.10.67 2022-01-012022-09-30 C001789 Vigilante Elec. Coop OLF 2022-01-012022-09-30 C001789 Energy Keepers Inc. AVA BPAT SFP MONTANA OATT AVAT.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 Montana Operationsferc:Quarter2Member 2022-01-012022-09-30 C001789 Macquarie Energy, LLC NWMT BPAT SFP MONTANA OATT TFALLS BPAT.NWMT 2022-01-012022-09-30 C001789 The Energy Authority PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT BPAT NF MONTANA OATT TFALLS BPAT.NWMT 2022-01-012022-09-30 C001789 2020-12-31 C001789 Magris Talc USA, Inc. Energy Keepers Inc. Magris Talc USA, Inc. FNO Montana OATT Kerr Three Forks, MT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT SFP MONTANA OATT HARDIN BPAT.NWMT 2022-01-012022-09-30 C001789 Montana Operationsferc:SeptemberMember 2022-01-012022-09-30 C001789 General Mills Operations, LLC Talen Energy General Mills Operations, LLC FNO Montana OATT Colstrip Great Falls, MT 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative WAPA WAPA LFP MONTANA OATT CROSSOVER GREATFALLS 2022-01-012022-09-30 C001789 Treasury Stock Activity 2022-01-012022-09-30 C001789 Guzman Energy, LLC PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Sibanye-Stillwater Energy Keepers Inc. Stillwater Mining Company FNO Montana OATT Kerr Various in Montana 2022-01-012022-09-30 C001789 Unbilled Revenues (South Dakota) 2022-09-30 C001789 Pension Plan (Montana) 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT PACE NF MONTANA OATT MATL.NWMT YTP 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT PACE NF MONTANA OATT MATL.NWMT BRDY 2022-01-012022-09-30 C001789 Asset Retirement Obligation (Montana) 2022-09-30 C001789 Dynasty Power Inc. BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Southwester Power Pool (MT) FNS 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Macquarie Energy, LLC NWMT AVA NF MONTANA OATT TFALLS AVAT.NWMT 2022-01-012022-09-30 C001789 South Dakota Operations 2022-01-012022-09-30 C001789 Guzman Energy, LLC BPAT PPW SFP MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Asset Retirement Obligation (South Dakota) 2022-07-012022-09-30 C001789 Energy Keepers FIP NWMT BPAT OLF MONTANA OATT KERR BPAT.NWMT 2022-01-012022-09-30 C001789 Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization 2022-01-012022-09-30 C001789 Asset Retirement Obligation (South Dakota) 2022-06-30 C001789 2022-07-012022-09-30 C001789 Excess Deferred Income Taxes (South Dakota) 2022-09-30 C001789 ferc:IntangiblePlantMemberferc:ElectricUtilityMember 2022-01-012022-09-30 C001789 Powerex Corporation BPAT WAPA NF MONTANA OATT BPAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. PACE NWMT NF MONTANA OATT BRDY MATL.NWMT 2022-01-012022-09-30 C001789 Roseburg Forest Products Company Talen Energy Roseburg Forest Products Company FNO Montana OATT Colstrip Missoula, MT 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT PPW SFP MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 Powerex Corporation NWMT BPAT NF MONTANA OATT MATL.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 Aberdeen Manufactured Gas Plant (South Dakota) - Docket NG 11-003 2022-06-30 C001789 FAS 112 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT SFP MONTANA OATT COLSTRIP MATL.NWMT 2022-01-012022-09-30 C001789 South Dakota Operationsferc:DecemberMember 2022-01-012022-09-30 C001789 Southwest Power Pool (SPP) SPP Various NF SCH 8 Various Various 2022-01-012022-09-30 C001789 Puget Sound Energy Marketing NWMT BPAT NF MONTANA OATT COLSTRIP BPAT.NWMT 2022-01-012022-09-30 C001789 MAG Energy Solutions WAPA BPAT NF MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative PPW WAPA NF MONTANA OATT YTP CROSSOVER 2022-01-012022-09-30 C001789 Amortization of 2021-01-012021-09-30 C001789 Puget Sound Energy Marketing NWMT BPAT SFP MONTANA OATT COLSTRIP BPAT.NWMT 2022-01-012022-09-30 C001789 Montana Public Service Commission (Montana) - Docket 2017.9.78 - Order 7568 2022-01-012022-09-30 C001789 Macquarie Energy, LLC NWMT BPAT SFP MONTANA OATT CANYONFERRY BPAT.NWMT 2022-01-012022-09-30 C001789 Shell Energy North America PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT NWMT SFP MONTANA OATT HARDIN MATL.NWMT 2022-01-012022-09-30 C001789 Guzman Energy, LLC AVA PPW NF MONTANA OATT AVAT.NWMT BRDY 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 Guzman Energy, LLC PPW AVA NF MONTANA OATT YTP AVAT.NWMT 2022-01-012022-09-30 C001789 Guzman Energy, LLC AVA PPW NF MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 Market Monitoring & Compliance 2022-01-012022-09-30 C001789 ferc:ElectricUtilityMember 2021-01-012021-09-30 C001789 2022-09-30 C001789 Bonneville Power Admin NF 2022-01-012022-09-30 C001789 EDF Trading North America, LLC AVA NWMT NF MONTANA OATT AVAT.NWMT NWMT.SYSTEM 2022-01-012022-09-30 C001789 Natural Gas Transmission Verification Program (Montana) - Docket D2016.11.88 2022-01-012022-09-30 C001789 Dynasty Power Inc. NWMT BPAT NF MONTANA OATT MATL.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 Montana Operations 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (Montana) 2022-09-30 C001789 Morgan Stanley Capital Group, Inc. AVA NWMT SFP MONTANA OATT AVAT.NWMT MATL.NWMT 2022-01-012022-09-30 C001789 Macquarie Energy, LLC PPW BPAT NF MONTANA OATT YTP BPAT.NWMT 2022-01-012022-09-30 C001789 The Energy Authority NWMT PPW NF MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 EDF Trading North America, LLC NWMT NWMT NF MONTANA OATT HARDIN NWMT.SYSTEM 2022-01-012022-09-30 C001789 LANGFORD, CITY OF WAPA LANGFORD LFP VOL 2 HURON 115 KV BUS LANGFORD 12.5 KV 2022-01-012022-09-30 C001789 South Dakota Operationsferc:FebruaryMember 2022-01-012022-09-30 C001789 BPA Residential Exchange Program (Montana) - Docket 2018.8.49 Order 7630; Annual Amortization 2022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT NF MONTANA OATT MATL.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. AVA WAPA NF MONTANA OATT AVAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Guzman Energy, LLC PPW AVA SFP MONTANA OATT YTP AVAT.NWMT 2022-01-012022-09-30 C001789 Transalta Energy Marketing (US) Inc. NWMT WAUW NF MONTANA OATT MATL.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Field Inventory (South Dakota) - Docket EL 14-106 2022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT NF MONTANA OATT HARDIN BPAT.NWMT 2022-01-012022-09-30 C001789 Transalta Energy Marketing (US) Inc. WAPA BPAT NF MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 The Energy Authority WAPA PPW NF MONTANA OATT CROSSOVER YTP 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (Montana) 2022-01-012022-09-30 C001789 2021-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA NWMT NF MONTANA OATT GLWND2 MATL.NWMT 2022-01-012022-09-30 C001789 Western Area Power Administration WAPA NWMT NF MONTANA OATT CROSSOVER NWMT.SYSTEM 2022-01-012022-09-30 C001789 Pension Plan (Montana) 2022-06-30 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT SFP MONTANA OATT MATL.NWMT BPAT.NWMT 2022-01-012022-09-30 C001789 FAS 106 (Montana) - Docket 93.6.24 and Docket 2009.9.129 2022-07-012022-09-30 C001789 Mercuria Energy America, LLC BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT PACE NF MONTANA OATT MATL.NWMT JEFF 2022-01-012022-09-30 C001789 EDF Trading North America, LLC NWMT BPAT SFP MONTANA OATT COLSTRIP BPAT.NWMT 2022-01-012022-09-30 C001789 Shell Energy North America PPW PPW NF MONTANA OATT BRDY MLCK 2022-01-012022-09-30 C001789 East River FNS 2022-01-012022-09-30 C001789 Unbilled Revenues (South Dakota) 2022-07-012022-09-30 C001789 Excess Deferred Income Taxes (Montana) 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA BPAT NF MONTANA OATT GLWND1 BPAT.NWMT 2022-01-012022-09-30 C001789 Basin Electric Power Cooperative PPW WAPA NF MONTANA OATT YTP GREATFALLS 2022-01-012022-09-30 C001789 Cycle Power Partners, LLC NWMT PACE NF MONTANA OATT HORSESHOE JEFF 2022-01-012022-09-30 C001789 Guzman Energy, LLC PPW PPW NF MONTANA OATT BRDY YTP 2022-01-012022-09-30 C001789 Macquarie Energy, LLC NWMT WAPA SFP MONTANA OATT COLSTRIP CROSSOVER 2022-01-012022-09-30 C001789 Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization 2022-07-012022-09-30 C001789 Energy Keepers Inc. NWMT BPAT SFP MONTANA OATT KERR BPAT.NWMT 2022-01-012022-09-30 C001789 Dynasty Power Inc. WAPA BPAT NF MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT NF MONTANA OATT COLSTRIP BPAT.NWMT 2022-01-012022-09-30 C001789 Bonneville Power Administration BPAT WAPA NF MONTANA OATT BPAT.NWMT GREATFALLS 2022-01-012022-09-30 C001789 Asset Retirement Obligation (Montana) 2022-01-012022-09-30 C001789 Brookfield Renewable Trading and Marketing LP BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Montana Operationsferc:Quarter3Member 2022-01-012022-09-30 C001789 Powerex Corporation PPW WAPA NF MONTANA OATT JEFF CROSSOVER 2022-01-012022-09-30 C001789 Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization 2022-09-30 C001789 Day Ahead & Real Time Admin 2022-01-012022-03-31 C001789 Unbilled Revenues (South Dakota) 2022-01-012022-09-30 C001789 ferc:Quarter2Member South Dakota Operations 2022-01-012022-09-30 C001789 PacifiCorp BPAT PPW SFP MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA PPW NF MONTANA OATT GLWND2 BRDY 2022-01-012022-09-30 C001789 Current Ad Valorem True-Up (South Dakota) - Docket GE98-001 2022-06-30 C001789 Supply: 2022-01-012022-09-30 C001789 The Energy Authority AVA PPW NF MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 Compensated Absences (Montana) - Docket 97.11.219 2022-07-012022-09-30 C001789 Western Area Power Administration WAPA NWMT NF MONTANA OATT GREATFALLS NWMT.SYSTEM 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. WAPA BPAT NF MONTANA OATT GREATFALLS BPAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. AVA PPW NF MONTANA OATT AVAT.NWMT BRDY 2022-01-012022-09-30 C001789 Macquarie Energy, LLC AVA WAPA SFP MONTANA OATT AVAT.NWMT CROSSOVER 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT BPAT LFP MONTANA OATT KERR BPAT.NWMT 2022-01-012022-09-30 C001789 Western Area Power Administration NWMT WAPA NF MONTANA OATT CANYONFERRY CROSSOVER 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT GWA NF MONTANA OATT COLSTRIP GLWND1 2022-01-012022-09-30 C001789 Guzman Energy, LLC BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Flow-through Income Taxes (Montana) 2022-09-30 C001789 ScheduleTransmissionOfElectricityByIsoOrRtoAbstract 2022-01-012022-09-30 C001789 Rainbow Electric Marketing Corp. AVA PPW SFP MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 SIS Studies 2022-01-012022-09-30 C001789 Manufactured Gas Plants (South Dakota) - Docket NG 11-003 2022-06-30 C001789 CP Energy Marketing (US) Inc. WAPA PPW NF MONTANA OATT CROSSOVER YTP 2022-01-012022-09-30 C001789 ConocoPhillips WAPA BPAT NF MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 Pension Plan (South Dakota) 2022-01-012022-09-30 C001789 Uniper Global Commodities North America LLC BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Natural Gas Transmission Verification Program (Montana) - Docket D2016.11.88 2022-09-30 C001789 Morgan Stanley Capital Group, Inc. GWA BPAT SFP MONTANA OATT GLWND2 BPAT.NWMT 2022-01-012022-09-30 C001789 Investment in Equity Securities 2022-01-012022-09-30 C001789 Other 2021-01-012021-09-30 C001789 Powerex Corporation BPAT PPW LFP MONTANA OATT BPAT.NWMT BRDY 2022-01-012022-09-30 C001789 Line Interconnection Studiesferc:TransmissionStudiesMember 2022-01-012022-09-30 C001789 Manufactured Gas Plants (South Dakota) - Docket NG 11-003 2022-09-30 C001789 PacifiCorp NWMT PPW NF MONTANA OATT COLSTRIP YTP 2022-01-012022-09-30 C001789 Debt Financing Costs 2021-01-012021-09-30 C001789 Rainbow Electric Marketing Corp. BPAT PPW NF MONTANA OATT BPAT.NWMT YTP 2022-01-012022-09-30 C001789 Line of Credit (Repayments) Borrowings, Net 2021-01-012021-09-30 C001789 The Energy Authority WAPA PPW NF MONTANA OATT CROSSOVER BRDY 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT BPAT SFP MONTANA OATT KERR BPAT.NWMT 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT PACE NF MONTANA OATT KERR ANTE 2022-01-012022-09-30 C001789 ferc:GenerationStudiesMember Optional Studies 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT AVA SFP MONTANA OATT KERR AVAT.NWMT 2022-01-012022-09-30 C001789 Tax Cut Jobs Act Deferral (South Dakota) - Docket NG-0095 and GE17-003 2022-09-30 C001789 Compensated Absences (Montana) - Docket 97.11.219 2022-09-30 C001789 Montana Operationsferc:Quarter4Member 2022-01-012022-09-30 C001789 ferc:GenerationStudiesMember FEA Studies 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (South Dakota) 2022-06-30 C001789 Basin Electric Power Cooperative AVA PPW NF MONTANA OATT AVAT.NWMT YTP 2022-01-012022-09-30 C001789 Excess Deferred Income Taxes (South Dakota) 2022-06-30 C001789 Montana Resources Talen Energy & Energy Keepers, Inc. Montana Resources FNO Montana OATT Colstrip & Kerr Butte, MT 2022-01-012022-09-30 C001789 ferc:GasUtilityMember 2022-01-012022-09-30 C001789 FAC Studiesferc:TransmissionStudiesMember 2022-01-012022-09-30 C001789 PacifiCorp PPW PPW SFP MONTANA OATT BRDY YTP 2022-01-012022-09-30 C001789 Montana Public Service Commission Consumer Counsel Taxes (Montana) - Dockets 2017.9.78 and 2018.10.67 2022-09-30 C001789 Other 2022-01-012022-09-30 C001789 Shell Energy North America PPW PPW NF MONTANA OATT YTP BRDY 2022-01-012022-09-30 C001789 Dynasty Power Inc. WAPA PPW NF MONTANA OATT CROSSOVER YTP 2022-01-012022-09-30 C001789 Energy Keepers Inc. NWMT WAUW SFP MONTANA OATT MATL.NWMT GREATFALLS 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. NWMT AVA NF MONTANA OATT HARDIN AVAT.NWMT 2022-01-012022-09-30 C001789 Shell Energy North America WAPA BPAT NF MONTANA OATT CROSSOVER BPAT.NWMT 2022-01-012022-09-30 C001789 EDF Trading North America, LLC PPW NWMT NF MONTANA OATT YTP NWMT.SYSTEM 2022-01-012022-09-30 C001789 ferc:OtherUtilityMember 2022-01-012022-09-30 C001789 Pension Plan (Montana) 2022-09-30 C001789 Rainbow Electric Marketing Corp. PPW WAPA NF MONTANA OATT BRDY GREATFALLS 2022-01-012022-09-30 C001789 EDF Trading North America, LLC AVA AVA NF MONTANA OATT COLSTRIP AVAT.NWMT 2022-01-012022-09-30 C001789 Morgan Stanley Capital Group, Inc. BPAT PPW NF MONTANA OATT BPAT.NWMT JEFF 2022-01-012022-09-30 C001789 Deferred Gas Storage Sales (Montana) - Docket D2001.1.1; Amortization 2001 - 2039 2022-06-30 C001789 Morgan Stanley Capital Group, Inc. NWMT GWA NF MONTANA OATT HARDIN GLWND1 2022-01-012022-09-30 C001789 Compensated Absences (Montana) - Docket 97.11.219 2022-01-012022-09-30 iso4217:USD utr:MW xbrli:pure utr:MWh ns:year
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
/
Q3


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
/
Q3
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)

09/30/2022
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)

11/07/2022
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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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. On November 1, 2022, NorthWestern acquired the intrastate natural gas operating system serving approximately 140 customers in and around the community of Winifred, MT. The acquisition received approval from the Montana Public Service Commission through Order 7830d. The acquisition price of $1 fell below the threshold requiring approval from FERC.
4. None
5. None
6. See Note 6, "Financing Activities." Equity issuance: FERC Order ES19-36-000 and MPSC Order Number 7691 Docket Number D2019.08.046; Amendment to Credit Facility: FERC Order ES21-53-000 and MPSC Order Number 7804 Docket Number D2021.08.107.
7. None
8. None
9. See Note 8, "Commitments and Contingencies".
10. None
12. None
13. On July 27, 2022, Bob Rowe, the current Chief Executive Officer of the company and member of the board of directors, announced his retirement at the end of 2022. On this same day, the board of directors appointed Brian Bird, currently the company's President and Chief Operating Officer, to serve as Chief Executive Officer effective January 1, 2023.
On July 28, 2022, the board of directors elected Kent Larson as a director to the board of directors to a term commencing immediately and expiring at the Company's next Annual Meeting of Stockholders, at which time Mr. Larson is expected to be nominated for approval by the Company's stockholders.
On August 31, 2022, Heather Grahame, the current General Counsel and Vice President - Regulatory and Federal Government Affairs, informed the company that she will retire from her position as of January 1, 2023. Effective January 1, 2023 Cyndee Fang will serve as Vice President - Regulatory, and Shannon Heim will serve as Vice President - General Counsel.
On August 31, 2022 the company also announced that Curtis Pohl will serve in a newly created role as Vice President - Asset Management and Business Development, effective September 1, 2022. On the same date, Jason Merkel succeeded Mr. Pohl and began serving as Vice President - Distribution.
14. NA


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
7,317,092,785
7,084,086,086
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200
444,609,825
284,729,122
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Enter Total of lines 2 and 3)
7,761,702,610
7,368,815,208
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)
200
2,779,479,996
2,648,396,212
6
UtilityPlantNet
Net Utility Plant (Enter Total of line 4 less 5)
4,982,222,614
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)
4,982,222,614
4,720,418,996
15
OtherElectricPlantAdjustments
Utility Plant Adjustments (116)
357,585,527
357,585,527
16
GasStoredUndergroundNoncurrent
Gas Stored Underground - Noncurrent (117)
36,195,927
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
24,809,730
24,377,535
23
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
228
24
OtherInvestments
Other Investments (124)
17,419,816
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)
42,887,081
43,297,089
33
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
34
CashAndWorkingFunds
Cash and Working Funds (Non-major Only) (130)
35
Cash
Cash (131)
7,202,308
2,300,750
36
SpecialDeposits
Special Deposits (132-134)
18,440,385
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)
70,799,624
86,846,850
41
OtherAccountsReceivable
Other Accounts Receivable (143)
17,152,023
8,867,792
42
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
2,505,531
2,319,115
43
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
44
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Assoc. Companies (146)
4,612,100
2,818,214
45
FuelStock
Fuel Stock (151)
227
6,162,988
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
68,187,565
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
1,309,870
55
GasStoredCurrent
Gas Stored Underground - Current (164.1)
54,159,825
18,828,613
56
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57
Prepayments
Prepayments (165)
(a)
24,961,950
22,690,392
58
AdvancesForGas
Advances for Gas (166-167)
59
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
60
RentsReceivable
Rents Receivable (172)
322,701
54,488
61
AccruedUtilityRevenues
Accrued Utility Revenues (173)
62,848,139
98,149,252
62
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
511,681
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)
331,569,138
314,225,109
68
DeferredDebitsAbstract
DEFERRED DEBITS
69
UnamortizedDebtExpense
Unamortized Debt Expenses (181)
10,205,185
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
709,012,397
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)
1,536,854
4,169
77
TemporaryFacilities
Temporary Facilities (185)
78
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
10,890,701
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)
23,359,278
25,635,857
82
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234
164,409,150
160,914,104
83
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
104,163,981
94,663,379
84
DeferredDebits
Total Deferred Debits (lines 69 through 83)
1,023,577,546
986,089,764
85
AssetsAndOtherDebits
TOTAL ASSETS (lines 14-16, 32, 67, and 84)
6,774,037,833
6,457,806,502


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
FOOTNOTE DATA

(a) Concept: Prepayments
South Dakota Operations Prepayments (165) are $19,965,007 and $14,201,612 for 2022 and 2021, respectively.

Montana Operations Prepayments (165) are $4,996,944 and $8,488,780 for 2022 and 2021, respectively.
(b) Concept: UnamortizedLossOnReacquiredDebt
Montana Operations Unamortized Loss on Reacquired Debt (189) is $20,969,627 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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
613,176
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
1,900,992,328
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
739,563,008
725,880,305
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118
45,487
446,074
13
ReacquiredCapitalStock
(Less) Reaquired Capital Stock (217)
250
98,578,347
98,248,245
14
NoncorporateProprietorship
Noncorporate Proprietorship (Non-major only) (218)
15
AccumulatedOtherComprehensiveIncome
Accumulated Other Comprehensive Income (219)
122(a)(b)
5,308,541
5,167,596
16
ProprietaryCapital
Total Proprietary Capital (lines 2 through 15)
2,537,327,111
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
385,000,000
373,000,000
22
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
23
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Debit (226)
40,139
61,389
24
LongTermDebt
Total Long-Term Debt (lines 18 through 23)
2,564,619,861
2,552,598,611
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases - Noncurrent (227)
10,237,251
12,829,411
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
(a)
6,086,315
7,061,829
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
(b)
3,980,613
6,434,213
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
76,203,332
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)
39,931,115
40,747,410
35
OtherNoncurrentLiabilities
Total Other Noncurrent Liabilities (lines 26 through 34)
136,438,626
155,602,920
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
NotesPayable
Notes Payable (231)
92,403
38
AccountsPayable
Accounts Payable (232)
158,622,563
120,452,816
39
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
40
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
4,159,320
3,931,236
41
CustomerDeposits
Customer Deposits (235)
11,434,846
8,573,478
42
TaxesAccrued
Taxes Accrued (236)
262
135,391,323
79,488,912
43
InterestAccrued
Interest Accrued (237)
26,817,788
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)
1,488,661
2,178,547
48
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
(c)
67,534,270
63,691,637
49
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
3,800,372
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)
409,341,546
300,897,052
55
DeferredCreditsAbstract
DEFERRED CREDITS
56
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
(d)
95,254,003
80,779,904
57
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
266
434,620
517,968
58
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
59
OtherDeferredCredits
Other Deferred Credits (253)
269
165,831,323
173,125,630
60
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
173,967,039
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)
444,305,543
431,345,154
64
AccumulatedDeferredIncomeTaxesOther
Accum. Deferred Income Taxes-Other (283)
246,518,161
237,568,898
65
DeferredCredits
Total Deferred Credits (lines 56 through 64)
1,126,310,689
1,108,994,323
66
LiabilitiesAndOtherCredits
TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)
6,774,037,833
6,457,806,502


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
FOOTNOTE DATA

(a) Concept: AccumulatedProvisionForInjuriesAndDamages
South Dakota Operations Provision for Injuries and Damages (228.2) are $758,818 and $570,311 for 2022 and 2021, respectively.

Montana Operations Provision for Injuries and Damages (228.2) are $5,327,498 and $6,491,517 for 2022 and 2021, respectively.
(b) Concept: AccumulatedProvisionForPensionsAndBenefits
Montana Operations Accumulated Provision for Pensions and Benefits (228.3) are $901,644 and $3,478,599 for 2022 and 2021, respectively.
(c) Concept: MiscellaneousCurrentAndAccruedLiabilities
Montana Operations Miscellaneous Current and Accrued Liabilities (242) are $50,810,860 and $46,613,454 for 2022 and 2021, respectively.
(d) Concept: CustomerAdvancesForConstruction
Montana Operations Customer Advances for Construction (252) are $95,254,003 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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
1,060,628,035
1,004,267,538
305,941,707
320,010,831
794,794,584
797,837,304
265,170,622
205,928,796
662,829
501,438
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
320
547,649,692
472,649,548
150,243,227
154,464,055
364,769,062
347,400,562
182,369,543
124,860,685
511,087
388,301
5
MaintenanceExpense
Maintenance Expenses (402)
320
41,975,343
39,300,425
14,395,255
13,537,093
35,779,801
34,246,467
6,144,708
4,987,464
50,835
66,494
6
DepreciationExpense
Depreciation Expense (403)
336
124,749,237
119,645,835
41,565,910
39,847,645
104,290,590
99,030,557
20,428,119
20,584,750
30,528
30,528
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336
9,754,395
9,595,731
3,288,820
3,379,079
5,464,311
4,863,963
4,290,084
4,731,768
9
AmortizationOfElectricPlantAcquisitionAdjustments
Amort. of Utility Plant Acq. Adj. (406)
336
11,326,329
11,326,329
3,775,443
3,775,443
11,961,208
11,961,208
634,879
634,879
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)
17,975,039
12,645,324
10,415,334
3,850,596
7,405,870
10,271,265
10,569,169
2,374,059
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
23,614,049
10,033,053
16,190,300
3,724,099
13,078,398
7,702,363
10,535,650
2,330,690
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262
146,205,879
144,942,100
48,564,347
45,651,701
113,695,979
112,897,491
32,459,739
31,995,119
50,160
49,490
15
IncomeTaxesOperatingIncome
Income Taxes - Federal (409.1)
262
11,216,872
6,193,312
3,400,020
12,152,116
4,401,451
2,239,172
6,806,823
3,958,074
8,598
3,934
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes - Other (409.1)
262
4,895,550
6,812,658
1,314,473
4,720,661
2,817,428
4,425,505
2,075,158
2,388,509
2,964
1,356
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision for Deferred Income Taxes (410.1)
234, 272
57,664,376
59,784,624
23,936,007
12,598,925
44,572,022
44,216,213
13,098,397
15,571,842
6,044
3,431
18
ProvisionForDeferredIncomeTaxesCreditOperatingIncome
(Less) Provision for Deferred Income Taxes-Cr. (411.1)
234, 272
74,570,716
71,164,440
29,585,215
27,827,080
51,258,576
47,940,965
23,312,140
23,223,475
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adj. - Net (411.4)
266
83,348
204
19,494
59
83,348
204
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)
3
2,678
3
1
3
2,678
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)
875,144,596
801,700,867
255,103,824
262,426,075
630,737,397
615,911,549
243,759,071
185,263,226
648,128
526,092
27
NetUtilityOperatingIncome
Net Util Oper Inc (Enter Tot line 2 less 25)
185,483,439
202,566,671
50,837,883
57,584,756
164,057,187
181,925,755
21,411,551
20,665,570
14,701
24,654
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)
440,198
744,028
163,458
352,385
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
177,728
85,953
97,952
29,272
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
105,640
4,337
48,815
2,382
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
407,505
633,220
114,831
179,469
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
400,587
503,479
105,960
38,824
37
InterestAndDividendIncome
Interest and Dividend Income (419)
1,419,423
1,343,999
313,883
1,042,928
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
9,983,225
7,821,166
3,330,316
3,264,729
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
1,070,632
1,454,731
1,134,977
55,303
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
41
OtherIncome
TOTAL Other Income (Enter Total of lines 31 thru 40)
9,892,034
10,145,609
2,305,122
4,359,556
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
45
Donations
Donations (426.1)
656,880
576,495
174,685
153,504
46
LifeInsurance
Life Insurance (426.2)
47
Penalties
Penalties (426.3)
2,519,800
91,744
89
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Exp. for Certain Civic, Political & Related Activities (426.4)
261,788
112,516
70,221
17,499
49
OtherDeductions
Other Deductions (426.5)
406,902
3,978,551
534,095
2,313,810
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
3,031,566
4,575,818
289,189
2,484,902
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262
2,097
25,733
699
2,234
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262
3,156,357
6,871,874
2,278,054
13,035,477
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262
853,349
1,802,426
1,291,306
1,488,948
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Inc. Taxes (410.2)
234, 272
15,461,873
32,351,228
1,396,682
25,393,985
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Cr. (411.2)
234, 272
10,626,222
21,651,711
4,488,242
10,204,963
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)
2,534,740
2,050,950
478,499
666,831
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
4,325,728
3,518,841
2,115,812
1,207,823
61
InterestChargesAbstract
Interest Charges
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
71,903,015
65,989,617
25,596,606
22,031,752
63
AmortizationOfDebtDiscountAndExpense
Amort. of Debt Disc. and Expense (428)
1,364,621
1,387,085
476,723
462,370
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reaquired Debt (428.1)
2,092,744
2,107,446
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)
2,524,887
4,508,910
457,579
1,823,175
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)
4,337,894
3,411,580
1,712,341
1,423,196
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
73,547,373
70,581,478
25,521,049
23,596,583
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
116,261,794
135,504,034
27,432,646
35,195,996
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)
116,261,794
135,504,034
27,432,646
35,195,996


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report


End of:
2022
/
Q3
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)
116,662,381
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
102,979,678
128,482,602
36
DividendsDeclaredCommonStock
TOTAL Dividends Declared-Common Stock (Acct. 438)
102,979,678
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)
739,563,008
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)
739,563,008
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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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)
116,261,794
135,504,034
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
124,749,237
119,645,835
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of
21,080,724
20,922,060
5.2
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other Noncash Charges to Income, Net
(a)
9,569,838
(f)
16,131,569
8
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
12,070,689
680,299
9
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustment (Net)
83,348
204
10
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
6,155,525
6,444,338
11
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
47,323,547
23,403,109
12
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
13
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
111,414,472
35,678,228
14
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
7,939,167
1,170,270
15
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
11,689,730
7,574,942
16
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
9,983,225
7,821,166
17
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
400,587
503,479
18
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other (provide details in footnote):
18.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other
(b)
7,564,867
(g)
72,262,002
22
NetCashFlowFromOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)
308,855,938
221,917,551
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)
366,315,930
279,913,515
27
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
28
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
30,871,596
40,398,233
29
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
30
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
9,983,225
7,821,166
31
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other (provide details in footnote):
34
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 26 thru 33)
387,204,301
312,490,582
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
913,517
655,221
57
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)
388,117,818
313,145,803
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
179,902,530
121,065,812
64
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other (provide details in footnote):
64.1
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription
Treasury Stock Activity
245,576
360,563
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)
180,240,509
221,341,375
72
PaymentsForRetirementAbstract
Payments for Retirement of:
73
PaymentsForRetirementOfLongTermDebtFinancingActivities
Long-term Debt (b)
955,280
74
PaymentsForRetirementOfPreferredStockFinancingActivities
Preferred Stock
75
PaymentsForRetirementOfCommonStockFinancingActivities
Common Stock
76
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Debt Financing Costs
1,315,178
909,219
76.2
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Line of Credit (Repayments) Borrowings, Net
12,000,000
73,000,000
78
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
100,000,000
80
DividendsOnPreferredStock
Dividends on Preferred Stock
81
DividendsOnCommonStock
Dividends on Common Stock
102,979,678
95,149,204
83
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)
87,945,653
97,327,672
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)
8,683,773
6,099,420
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)
25,665,943
(i)
21,496,866


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
FOOTNOTE DATA

(a) Concept: NoncashAdjustmentsToCashFlowsFromOperatingActivities
9/30/2022 9/30/2021
Other Noncash Charges to Income, Net:
Amortization of debt issue costs, discount, and deferred hedge gain 4,989,099  3,953,839 
Other noncash gains 256,502  6,327,787 
Stock based compensation costs 4,324,237  5,849,943 
9,569,838  16,131,569 
Other Assets and Liabilities, Net:
Net change - other current assets (2,793,347) (6,982,111)
Net change - accrued utility revenues 35,301,113  22,308,011 
Net change - deferred debits (12,964,561) (83,555,808)
Net change - deferred credits (8,863,467) 27,216,685 
Net change - noncurrent liabilities (18,244,605) (31,248,779)
(7,564,867) (72,262,002)
(b) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
Refer to footnote (a) for details.
(c) Concept: OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Increase in Notes payable (231)
(d) Concept: CashAndCashEquivalents
9/30/2022 12/31/2021 9/30/2021 12/31/2020
Cash (131) 7,202,308  2,300,750  7,118,962  5,454,203 
Working Funds (135) 23,250  23,250  22,950  22,950 
Special Funds (125-128) —  —  —  250,000 
Other Special Deposits (134) 18,440,385  14,658,170  14,354,954  9,670,293 
Total 25,665,943  16,982,170  21,496,866  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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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 June 30, 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 $509.3 million and $479.3 million as of September 30, 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 September 30, 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 September 30, 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 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 and nine months ended 2022 and 2021 (in millions):
Three Months Ended September 30, 2022
TotalElectricNatural GasOther
GAAP Revenues$335.0 $292.3 $42.7 $— 
Revenue from equity investments(0.7)— (0.7)— 
Grossing revenues / power purchases1.6 1.6 — — 
Regulatory amortizations(26.9)(21.4)(5.5)— 
Other(3.1)(2.9)(0.2)— 
FERC Revenues$305.9 $269.6 $36.3 $— 

Three Months Ended September 30, 2021
TotalElectricNatural GasOther
GAAP Revenues$326.0 $287.5 $38.5 $— 
Revenue from equity investments(0.8)— (0.8)— 
Grossing revenues / power purchases7.5 7.5 — — 
Regulatory amortizations(14.9)(9.6)(5.3)— 
Other2.2 2.4 (0.2)— 
FERC Revenues$320.0 $287.8 $32.2 $— 
Nine Months Ended September 30, 2022
TotalElectricNatural GasOther
GAAP Revenues$1,052.5 $807.4 $245.1 $— 
Revenue from equity investments(2.2)— (2.2)— 
Grossing revenues / power purchases24.7 24.7 — — 
Regulatory amortizations(10.9)(34.3)23.4 — 
Other(3.5)(3.0)(1.1)0.6 
FERC Revenues$1,060.6 $794.8 $265.2 $0.6 

Nine Months Ended September 30, 2021
TotalElectricNatural GasOther
GAAP Revenues$1,025.0 $799.0 $226.0 $— 
Revenue from equity investments(2.3)— (2.3)— 
Grossing revenues / power purchases23.1 23.1 — — 
Regulatory amortizations(44.9)(28.1)(16.8)— 
Other3.4 3.8 (0.9)0.5 
FERC Revenues$1,004.3 $797.8 $206.0 $0.5 
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):

September 30, 2022December 31, 2021September 30, 2021December 31, 2020
Cash$7,202 $2,301 $7,119 $5,454 
Working funds23 23 23 23 
Other special funds— — — 250 
Special deposits18,440 14,658 14,355 9,670 
Total shown in the Statements of Cash Flows$25,665 $16,982 $21,497 $15,397 

Utility Plant Adjustment

We completed our annual utility plant adjustment impairment test as of April 1, 2022 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

Montana Rate Review

On August 8, 2022, we filed a Montana electric and natural gas rate review with the Montana Public Service Commission (MPSC) requesting an annual increase to electric and natural gas utility rates of $171.0 million and $23.0 million, respectively, detailed as follows:

Requested Revenue Increase (in millions)
ElectricNatural Gas
Base Rates$91.8$20.2
Power Cost & Credit Mechanism (PCCAM)(1)
$68.1n/a
Property Tax (tracker true-up)(1)
$11.1$2.8
Total$171.0$23.0
(1) These items are flow-through costs, which represent approximately 42% of the requested electric and natural gas revenue increase.

Our electric request is based on a return on equity of 10.60% with a forecasted 2022 rate base of $2.8 billion and a capital structure of 51.98% debt and 48.02% equity. Our natural gas request is based on a return on equity of 10.60% with a forecasted 2022 rate base of $575.3 million and a capital structure of 51.98% debt and 48.02% equity.

Within this rate review filing we requested an increase to the Power Cost and Credit Mechanism (PCCAM) base rate (PCCAM Base) of $68.1 million, as well as structural revisions to the PCCAM mechanism to provide customers with prices that better reflect the cost of services received. We also proposed to implement a revised electric only pilot for the Fixed Cost Recovery Mechanism (FCRM) beginning July 1, 2023, or alternatively to terminate the FCRM. Our rate review filing also includes proposals for more timely cost recovery beyond the test period, including critical reliability resources, such as the Yellowstone Generating Station, our Enhanced Wildfire Mitigation plan, and business technology maintenance costs.
On September 28, 2022, the MPSC approved the recommendations of the MPSC Staff for interim rates, subject to refund, which increased base electric rates $29.4 million, PCCAM Base rates $61.1 million, and base natural gas rates $1.7 million, effective October 1, 2022.

Montana Community Renewable Energy Projects (CREPs)

As further discussed in Note 3 - "Regulatory Matters" of our Annual FERC Form 1 Report for the year ended December 31, 2021, we have been involved in litigation associated with our past progress towards meeting obligations to acquire renewable energy projects, as mandated by the recently repealed Montana CREP requirement. Although we had been granted waivers by the Montana Public Service Commission (MPSC) and the CREP requirement was subsequently repealed by the Montana legislature, on May 9, 2022, the Montana District Court imposed a $2.5 million penalty against us, payable to the Universal Low Income Assistance Fund in Montana, in connection with the petition filed by the Montana Environmental Information Center challenging the MPSC's decision granting our waiver requests from CREP compliance in 2015 and 2016. The expense associated with this penalty has been accrued for within our second quarter 2022 results. We filed an appeal with the Montana Supreme Court.

Federal Energy Regulatory Commission (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 October 31, 2021 to evaluate our compliance with FERC accounting and financial reporting requirements. In May 2022, we received the final audit report from FERC and the resolution of the identified audit findings and recommendations did not have a material financial impact on our Financial Statements.
(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 September 30,
20222021
Income Before Income Taxes$26,895 $32,887 
Income tax calculated at federal statutory rate5,647 21.0 %6,906 21.0 %
Permanent or flow-through adjustments:
State income tax, net of federal provisions145 0.5 397 1.2 
Flow-through repairs deductions(3,374)(12.5)(3,473)(10.6)
Production tax credits(1,668)(6.2)(1,877)(5.7)
Prior year permanent return to accrual adjustments(926)(3.4)389 1.2 
Amortization of excess deferred income tax(246)(0.9)(126)(0.4)
Share-based compensation— — (62)(0.2)
Plant and depreciation of flow-through items266 1.0 (288)(0.9)
Other, net(320)(1.3)443 1.4 
(6,123)(22.8)(4,597)(14.0)
Income tax expense $(476)(1.8)%$2,309 7.0 %

Nine Months Ended September 30,
20222021
Income Before Income Taxes117,917 131,853 
Income tax calculated at federal statutory rate$24,763 21.0 %$27,689 21.0 %
Permanent or flow-through adjustments:
State income tax, net of federal provisions976 0.8 674 0.5 
Flow-through repairs deductions(13,488)(11.4)(15,553)(11.8)
Production tax credits(8,050)(6.8)(8,446)(6.4)
Prior year permanent return to accrual adjustments(926)(0.8)389 0.3 
Amortization of excess deferred income tax(819)(0.7)(534)(0.4)
Share-based compensation(253)(0.2)(323)(0.2)
Plant and depreciation of flow-through items409 0.3 (812)(0.6)
Other, net(957)(0.8)567 0.4 
(23,108)(19.6)(24,038)(18.2)
Income tax expense $1,655 1.4 %$3,651 2.8 %
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 $30.8 million as of September 30, 2022, including approximately $28.0 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 September 30, 2022, we have accrued $1.1 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):

September 30, 2022December 31, 2021
Havre Pipeline Company, LLC$11,628 $12,130 
Canadian Montana Pipeline Corporation5,014 4,867 
NorthWestern Energy Solutions, Inc.4,943 4,126 
NorthWestern Services, LLC2,080 2,065 
Risk Partners Assurance, Ltd.1,145 1,190 
Total Investments in Subsidiary Companies$24,810 $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
September 30, 2022September 30, 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$(5)$— $(5)$(1)$— $(1)
Reclassification of net income (loss) on derivative instruments153 (40)113 153 (40)113 
Postretirement medical liability adjustment(212)54 (158)(212)53 (159)
Other comprehensive income$(64)$14 $(50)$(60)$13 $(47)
Nine Months Ended
September 30, 2022September 30, 2021
Before-
Tax Amount
Tax
Expense (Benefit)
Net-of-
Tax Amount
Before-
Tax Amount
Tax
Expense (Benefit)
Net-of-
Tax Amount
Foreign currency translation adjustment$(6)$— $(6)$(56)$— $(56)
Reclassification of net income (loss) on derivative instruments459 (120)339 459 (120)339 
Postretirement medical liability adjustment(636)162 (474)(636)160 (476)
Other comprehensive income$(183)$42 $(141)$(233)$40 $(193)

Balances by classification included within accumulated other comprehensive income (AOCI) on the Balance Sheets are as follows, net of tax (in thousands):

September 30, 2022December 31, 2021
Foreign currency translation$1,437 $1,443 
Derivative instruments designated as cash flow hedges(7,788)(8,127)
Postretirement medical plans1,042 1,516 
Accumulated other comprehensive income$(5,309)$(5,168)

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


Three Months Ended September 30, 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$(7,901)$1,200 $1,442 $(5,259)
Other comprehensive income before reclassifications— — (5)(5)
Amounts reclassified from AOCIInterest on long-term debt113 — — 113 
Amounts reclassified from AOCI— (158)— (158)
Net current-period other comprehensive income113 (158)(5)(50)
Ending balance$(7,788)$1,042 $1,437 $(5,309)
Three Months Ended September 30, 2021
Affected Line Item in the Statements of Income
Interest Rate Derivative Instruments
Designated as Cash Flow Hedges
Postretirement Medical Plans
Foreign
Currency
Translation
Total
Beginning balance$(8,353)$1,635 $1,446 $(5,272)
Other comprehensive income before reclassifications— — (1)(1)
Amounts reclassified from AOCIInterest on long-term debt113 — — 113 
Amounts reclassified from AOCI— (159)— (159)
Net current-period other comprehensive income113 (159)(1)(47)
Ending balance$(8,240)$1,476 $1,445 $(5,319)

Nine Months Ended September 30, 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 $(5,168)
Other comprehensive income before reclassifications— — (6)(6)
Amounts reclassified from AOCIInterest on long-term debt339 — — 339 
Amounts reclassified from AOCI— (474)— (474)
Net current-period other comprehensive income339 (474)(6)(141)
Ending balance$(7,788)$1,042 $1,437 $(5,309)
Nine Months Ended September 30, 2021
Affected Line Item in the Statements of Income
Interest Rate Derivative Instruments
Designated as Cash Flow Hedges
Postretirement Medical Plans
Foreign
Currency
Translation
Total
Beginning balance$(8,579)$1,952 $1,501 $(5,126)
Other comprehensive income before reclassifications— — (56)(56)
Amounts reclassified from AOCIInterest on long-term debt339 — — 339 
Amounts reclassified from AOCI— (476)— (476)
Net current-period other comprehensive income339 (476)(56)(193)
Ending balance$(8,240)$1,476 $1,445 $(5,319)
(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.

On June 24, 2022, we partially settled the forward sale agreement by physically delivering 2,004,483 shares of common stock in exchange for cash proceeds of $99.9 million, net of issuance costs. Additionally, on September 21, 2022, we partially settled the forward sale agreement by physically delivering 1,618,932 shares of common stock in exchange for cash proceeds of approximately $80.0 million, net of issuance costs. The proceeds were used to pay down borrowings under our revolving credit facility and for other general corporate purposes.

At September 30, 2022, the remaining obligation under the forward agreements could have been settled with physical delivery of 1,960,698 common shares to the banking counterparty in exchange for cash of $96.9 million. The forward agreements could have also been settled at September 30, 2022, with delivery of $10.3 million of cash or 186,254 shares of common stock to the counterparty, if we elected net cash or net share settlement, respectively.
On May 18, 2022, we entered into an amendment and restatement of our existing $425.0 million revolving credit facility to, among other things, change the Eurodollar rate to the secured overnight financing rate as administered by the Federal Reserve Bank of New York (SOFR) and extend the maturity date of the facility from September 2, 2023 to May 18, 2027. The amended and restated credit facility (the Primary Credit Facility) maintains the same capacity at $425.0 million and uncommitted features that allow us to request up to two one-year extensions to the maturity date and increase the size of the facility by up to an additional $75.0 million. The Primary Credit Facility does not amortize and is unsecured. Borrowings may be made at interest rates equal to (a) SOFR, plus a credit spread adjustment of 10.0 basis points and plus a margin of 100.0 to 175.0 basis points, or (b) a base rate, plus a margin of 0.0 to 75.0 basis points.

On October 28, 2022 we entered into a $100.0 million Credit Agreement (the Additional Credit Facility) to supplement our existing $425.0 million revolving credit facility. The Additional Credit Facility has a maturity date of April 28, 2024. The Additional Credit Facility does not amortize and is unsecured. Borrowings may be made at interest rates equal to (a) SOFR, plus a credit spread adjustment of 10.0 basis points, plus a margin of 100.0 to 175.0 basis points, or (b) a base rate, plus a margin of 0.0 to 75.0 basis points.
(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):

September 30, 2022December 31, 2021
Accounts Receivable from Associated Companies:
Havre Pipeline Company, LLC$4,523 $2,729 
NorthWestern Energy Solutions, Inc.71 71 
Risk Partners Assurance, Ltd.18 18 
$4,612 $2,818 
Accounts Payable to Associated Companies:
NorthWestern Services, LLC$1,861 $2,094 
Canadian Montana Pipeline Corporation2,298 1,837 
$4,159 $3,931 
(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 September 30, Three Months Ended September 30,
2022202120222021
Components of Net Periodic Benefit Cost (Credit)
Service cost$2,555 $3,275 $88 $103 
Interest cost4,697 4,704 90 79 
Expected return on plan assets(6,043)(6,841)(262)(230)
Amortization of prior service credit— — (472)(459)
Recognized actuarial loss (gain)96 1,744 (13)(8)
Net periodic benefit cost (credit)$1,305 $2,882 $(569)$(515)

Pension BenefitsOther Postretirement Benefits
Nine Months Ended September 30, Nine Months Ended September 30,
2022202120222021
Components of Net Periodic Benefit Cost (Credit)
Service cost$7,667 $9,824 $263 $306 
Interest cost14,090 14,114 269 238 
Expected return on plan assets(18,129)(20,525)(785)(689)
Amortization of prior service credit— — (1,418)(1,377)
Recognized actuarial loss (gain)287 5,233 (37)(23)
Net periodic benefit cost (credit)$3,915 $8,646 $(1,708)$(1,545)

We have contributed $8.2 million to our pension plans during the nine months ended September 30, 2022. We expect to contribute $3.0 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 19 - 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 $23.4 million to $30.0 million. As of September 30, 2022, we had a reserve of approximately $25.4 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 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) and methane emissions from natural gas. These actions include legislative proposals, Executive, Congressional 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. However, Section 111(d) of the Clean Air Act (CAA) confers authority on EPA and the states to regulate emissions, including GHGs, from existing stationary sources. EPA has acted on this authority, including in 2015 when it sought to implement the Clean Power Plan that would establish rules to control GHG emissions from existing power plants. However, neither the Clean Power Plan nor any other subsequent attempts by the EPA to regulate emissions from coal-fired plants 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, in other words, establish a carbon emission cap based on a power generation source shift. The litigation culminated in the United States Supreme Court's June 30, 2022 ruling in West Virginia, et al., v. Environmental Protection Agency, et al, in which the Court held that the EPA does not have the authority to force major changes in the U.S. electric generation mix, as that would expand EPA's regulatory authority. In addition, the U.S. Supreme Court concluded that EPA could not meet its burden under the "major questions doctrine" to point to clear congressional authorization for this authority. The U.S. Supreme Court's ruling, however, declined to decide whether the Section 111(d) phrase "system of emissions reduction" refers exclusively to individual source control at coal-fired plants or broader energy-generating industry-wide approaches.

As expected, subsequent to that ruling, EPA opened a docket to collect public input to guide the EPA’s next effort to reduce GHG emissions from new and existing coal fired plants and natural gas operations. EPA indicated that it intends to use this non-rulemaking docket to gather perspectives from a broad group of stakeholders in advance of an expected proposed rulemaking.

Therefore, we cannot predict whether or how future GHG emission regulations or litigation will impact our plants, including any actions taken by federal or state authorities, or courts. 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 - federal or state - 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, wind, 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 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.

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 were 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 District Court ruled that the four agreements were valid and enforceable contracts and that we 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. Briefing has concluded, and we expect that the Ninth Circuit will hear oral arguments before rendering a decision.

While the Ninth Circuit had encouraged the parties to engage in a voluntary court-supervised mediation, the Court has subsequently determined that further discussions would be unproductive and released both parties from the mediation process.

Talen Montana Bankruptcy

On May 9, 2022 Talen Energy Supply, LLC (Talen Energy) along with 71 affiliated entities, filed bankruptcy in Houston, Texas, seeking reorganization under Chapter 11 (the Talen Bankruptcy). Talen Montana, LLC (Talen) was one of the affiliated entities that filed bankruptcy and is included as a part of the Talen Bankruptcy. Talen is one of the co-owners of Colstrip Units 1, 2 and 3, and the operator of Units 3 and 4. The Talen Bankruptcy filing, along with the automatic stay under §362 of the Bankruptcy Code, affects pending legal proceedings in which both NorthWestern and Talen are involved, including the State of Montana-Riverbed Rents Litigation, the Colstrip Arbitration and Litigation, and the Colstrip Coal Dust
Litigation, as described in the individual matters below. As the Talen Bankruptcy is in its early stages, we are unable to predict the ultimate effect, if any, on Colstrip Units 3 and 4, or other matters in which both NorthWestern and Talen are presently engaged.

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 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. Damages were bifurcated by agreement and will be tried separately, should the Federal District Court find any segments navigable.

On April 29, 2022, the parties submitted amended findings of fact and conclusions of law, along with post-trial briefing. The parties, other than Talen, filed responses on May 13, 2022. Talen did not file a response, as it had filed bankruptcy on May 9, 2022. In its response, the State sought to sever Talen and proceed solely against NorthWestern and the United States. A decision on navigability was expected following these submissions. However, the Talen Bankruptcy and resulting automatic stay, resulted in a hold on this case, including a hold on any decision regarding navigability and the State's severance request. The Federal District Court, by order issued June 23, 2022, confirmed it will not rule on the severance until the bankruptcy stay is lifted or ends. On July 16, 2022, Talen filed an adversary complaint in Talen's Bankruptcy, asking the Bankruptcy Court to extend the stay to NorthWestern. Before resolution of the adversary complaint, the parties stipulated and the Bankruptcy Court issued its Order modifying the stay to permit Talen to file its response to the State's amended proposed findings and conclusions and allow the Federal District Court to issue its decision on the navigability phase of the case. The Federal District Court is free to issue its decision on navigability. The damages phase of the case remains stayed.

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 MEIC 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 may experience a negative impact on our transmission revenue due to reduced amounts of energy transmitted across our transmission lines.

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.

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. Four of the six joint owners of Units 3 and 4 (The Pacific Northwest Owners) have asserted that 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 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 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. However, the Talen Bankruptcy and automatic stay resulted in a hold on this case, including a hold on any decision regarding NorthWestern’s motion to compel arbitration. On August 25, 2022, the Bankruptcy Court approved a stipulation entered into by Talen, the Pacific Northwest Owners and NorthWestern to modify the automatic stay, to allow the Magistrate Judge to issue her ruling regarding SB 265, SB 266 and to permit the parties to proceed to arbitration.

On September 28, 2022, the Magistrate Judge recommended that SB 265 be found pre-empted by the Federal Arbitration Act and in violation of the contracts clauses of both the United States’ and Montana Constitutions. She also recommended that SB 266 be found to violate the contracts clauses of the United States and Montana Constitutions and the commerce clause of the United States Constitution. All parties had until October 12, 2022, to object to the Magistrate Judge's recommendations. No objections were made. On October 18, 2022, the Federal District Court Judge adopted the Magistrate Judge's recommendations, in full, and entered a final order granting summary judgment as recommended.

The three initiated lawsuits do not make direct financial demands, and instead, address issues related to the process for the Arbitration and for closure of the facility. The pendency of the lawsuits and Talen's Bankruptcy have 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, the operator of the Colstrip Units 1, 2, 3 and 4 (Colstrip), 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 Colstrip. 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 Colstrip, 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. Talen’s bankruptcy and resulting automatic stay prevents the plaintiffs from pursuing their claims against Talen, but does not automatically prevent the plaintiffs from pursuing their claims against the other defendants. On September 26, 2022 the Bankruptcy Court extended the stay as to Talen and the other defendants until 60 days after the date Talen’s plan of reorganization is confirmed by the Bankruptcy Court.

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

BNSF Demands for Indemnity and Remediation Costs

NorthWestern has received a demand for indemnity from BNSF Railway Company (BNSF) for past and future environmental investigation and remediation costs incurred by BNSF at one of the three operable units at the Anaconda Copper Mining (ACM) Smelter and Refinery Superfund Site, located near Great Falls, Montana. Smelter and refining operations at the site commenced in 1893 and continued until 1980.

According to U.S. EPA, the smelter and refining operations have contaminated soil, groundwater and surface water resources around the site with lead, arsenic and other metal wastes. ARCO (Atlantic Richfield Company) initiated reclamation and maintenance activities in the 1980s and 1990s. Between 2002 and 2008, the EPA conducted several site investigations. In March 2011, the EPA placed the ACM Smelter and Refinery Site on the Superfund program’s National Priority List. The Superfund Site is 427 acres and contains three operable units: Operable Unit 1 (consisting of five subsections including the Railroad Corridor and four other “areas of interest”), Operable Unit 2 (the former smelter and refinery site), and Operable Unit 3 (the Missouri River that flows along the south sides of Operable Units 1 and 2).

NorthWestern owns property in the Railroad Corridor sub-section of Operable Unit 1. BNSF claims it is entitled to indemnity and contribution from NorthWestern for the costs it has and will incur to investigate and remediate contamination in Operable Unit 1. BNSF reports it has incurred in excess of $4.4 million, pending final resolution of response and oversight costs incurred by government agencies (EPA and Montana DEQ), in investigative and other response costs associated with Operable Unit 1, and that in the future it will incur additional costs to implement the final remedy for Operable Unit 1. In the Record of Decision (ROD) for Operable Unit 1 issued on August 21, 2021, the EPA estimated the costs to implement the selected remedies for the Railroad Corridor will be approximately $4.1 million. In the ROD, the EPA also estimated the costs to implement the selected remedy (including institutional controls) for the four “areas of interest” in Operable Unit 1 would be approximately $1.8 million, with annual operating costs of ten thousand dollars. We are evaluating BNSF’s claim and are unable at this time to predict outcomes or estimate a range of reasonably possible losses.

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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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)
476,230
(e)
339,098
137,132
3
Preceding Quarter/Year to Date Changes in Fair Value
(c)
56,025
56,025
4
Total (lines 2 and 3)
476,230
56,025
339,098
193,157
135,504,034
135,310,877
5
Balance of Account 219 at End of Preceding Quarter/Year
1,478,526
1,443,242
8,241,070
5,319,302
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)
475,230
(f)
339,097
136,133
8
Current Quarter/Year to Date Changes in Fair Value
(d)
4,812
4,812
9
Total (lines 7 and 8)
475,230
4,812
339,097
140,945
116,261,794
116,120,849
10
Balance of Account 219 at End of Current Quarter/Year
1,043,231
1,437,169
7,788,941
5,308,541


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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)
6,580,739,174
5,108,198,362
1,207,624,703
(a)
1,528,777
263,387,332
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
41,605,010
(b)
40,209,537
(c)
1,395,473
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)
6,626,436,969
5,112,291,147
1,207,624,703
1,528,777
40,209,537
1,395,473
263,387,332
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
4,327,381
4,297,515
29,866
11
ConstructionWorkInProgress
Construction Work in Progress
444,609,825
338,160,612
84,657,676
21,791,537
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
686,328,435
686,328,435
13
UtilityPlantAndConstructionWorkInProgress
Total Utility Plant (8 thru 12)
7,761,702,610
6,141,077,709
1,292,312,245
1,528,777
40,209,537
1,395,473
285,178,869
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
2,779,479,996
2,137,768,926
529,856,886
1,077,742
32,670,229
78,106,213
15
UtilityPlantNet
Net Utility Plant (13 less 14)
4,982,222,614
4,003,308,783
762,455,359
451,035
7,539,308
1,395,473
207,072,656
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
2,506,316,095
1,944,875,847
475,528,491
1,077,742
32,670,229
52,163,786
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
47,575,530
47,575,530
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
56,660,178
23,964,886
6,752,865
25,942,427
22
DepreciationAmortizationAndDepletionUtilityPlantInService
Total in Service (18 thru 21)
2,610,551,803
1,968,840,733
529,856,886
1,077,742
32,670,229
78,106,213
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
168,928,193
168,928,193
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Total Accum Prov (equals 14) (22,26,30,31,32)
2,779,479,996
2,137,768,926
529,856,886
1,077,742
32,670,229
78,106,213


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
27,943,389
9,910,383
2
Steam Production Plant
406,563,985
146,918,428
3
Nuclear Production Plant
4
Hydraulic Production - Conventional
589,021,198
145,099,144
5
Hydraulic Production - Pumped Storage
6
Other Production
577,437,543
151,654,009
7
Transmission
1,268,094,590
498,015,540
8
Distribution
2,070,501,579
916,968,452
9
Regional Transmission and Market Operation
10
General
172,728,863
100,274,777
11
TOTAL (Total of lines 1 through 10)
5,112,291,147
1,968,840,733


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
31,070
59,019
3
SIS Studies
84,666
100,586
4
Line Interconnection Studies
30,273
52,283
20
Total
146,009
211,888
21
Generation Studies
22
FAC Studies
131,993
811,857
23
SIS Studies
139,415
556,021
24
FEA Studies
102,388
211,644
25
Optional Studies
3,206
50,322
39
Total
370,590
1,629,844
40 Grand Total
516,599
1,841,732


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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)
422,253,569
6,514,132
428,767,701
2
Excess Deferred Income Taxes (Montana)
50,597,809
969,498
49,628,311
3
Basin Creek Capital Lease (Montana)
5,345,721
242,879
5,102,842
4
BPA Residential Exchange Program (Montana) - Docket 2018.8.49 Order 7630; Annual Amortization
976,748
1,515,535
1,315,149
1,177,134
5
Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization
1,048,350
5,059,982
6,108,332
6
FAS 106 (Montana) - Docket 93.6.24 and Docket 2009.9.129
4,329,901
73,110
4,256,791
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
12,378,098
658,221
11,719,877
9
Pension Plan (Montana)
90,378,421
1,326,643
89,051,778
10
Montana Consumer Counsel Tax (Montana) - Docket 2018.10.67 - Order 7637
612,676
26,675
639,351
11
Montana Public Service Commission (Montana) - Docket 2017.9.78 - Order 7568
3,867,486
85,868
290,156
3,663,198
12
Natural Gas Transmission Verification Program (Montana) - Docket D2016.11.88
898,133
156,943
741,190
13
Study of the Costs & Benefits of Customer Generators (Montana)
5,064
5,064
14
Asset Retirement Obligation (Montana)
13,821,584
595,464
14,417,048
15
Flow-through Income Taxes (South Dakota)
63,154,307
817,442
63,971,749
16
Excess Deferred Income Taxes (South Dakota)
6,984,448
33,758
6,950,690
17
Pension Plan (South Dakota)
5,304,230
5,304,230
18
Manufactured Gas Plants (South Dakota) - Docket NG 11-003
11,094,775
96,878
10,997,897
19
Field Inventory (South Dakota) - Docket EL 14-106
307,149
22,479
284,670
20
Asset Retirement Obligation (South Dakota)
803,476
33,104
836,580
44
TOTAL
699,554,973
14,648,202
5,190,778
709,012,397


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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)
133,749,310
1,407,858
72,199
132,413,651
2
Deferred Gas Storage Sales (Montana) - Docket D2001.1.1; Amortization 2001 - 2039
7,256,202
105,129
7,151,073
3
Montana Public Service Commission Consumer Counsel Taxes (Montana) - Dockets 2017.9.78 and 2018.10.67
1,849,306
21,264
36,150
1,864,192
4
CTC QF Over/Under Collections (Montana) - Docket 97.9.90 and Docket 2001.1.15; Annual Amortization
926,331
183,370
1,109,701
5
Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization
6
Natural Gas Regulatory Deferrals (Montana)
233,677
136,226
97,451
7
Excess Deferred Income Taxes (South Dakota)
20,246,635
215,074
20,031,561
8
Current Ad Valorem True-Up (South Dakota) - Docket GE98-001
271,436
32,581
195,628
434,483
9
Aberdeen Manufactured Gas Plant (South Dakota) - Docket NG 11-003
634,546
48,136
586,410
10
Tax Cut Jobs Act Deferral (South Dakota) - Docket NG-0095 and GE17-003
155,000
155,000
11
Unbilled Revenues (South Dakota)
8,141,170
1,982,347
10,123,517
41 TOTAL
173,463,613
1,966,268
2,469,694
173,967,039


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
306,826,010
2,587,204
3
CommercialAndIndustrialSalesAbstract
(442) Commercial and Industrial Sales
4
CommercialSalesAbstract
Small (or Comm.) (See Instr. 4)
331,130,227
2,914,819
5
IndustrialSalesAbstract
Large (or Ind.) (See Instr. 4)
55,154,600
570,125
6
PublicStreetAndHighwayLightingAbstract
(444) Public Street and Highway Lighting
11,848,397
30,096
7
OtherSalesToPublicAuthoritiesAbstract
(445) Other Sales to Public Authorities
718,907
5,822
8
SalesToRailroadsAndRailwaysAbstract
(446) Sales to Railroads and Railways
9
InterdepartmentalSalesAbstract
(448) Interdepartmental Sales
618,519
5,423
10
SalesToUltimateConsumersAbstract
TOTAL Sales to Ultimate Consumers
706,296,660
6,113,489
11
SalesForResaleAbstract
(447) Sales for Resale
19,846,544
753,214
12
SalesOfElectricityAbstract
TOTAL Sales of Electricity
726,143,204
6,866,703
13
ProvisionForRateRefundsAbstract
(Less) (449.1) Provision for Rate Refunds
1,970,746
14
RevenuesNetOfProvisionForRefundsAbstract
TOTAL Revenues Before Prov. for Refunds
728,113,950
6,866,703
15
OtherOperatingRevenuesAbstract
Other Operating Revenues
16
ForfeitedDiscounts
(450) Forfeited Discounts
357,697
17
MiscellaneousServiceRevenues
(451) Miscellaneous Service Revenues
163,948
18
SalesOfWaterAndWaterPower
(453) Sales of Water and Water Power
19
RentFromElectricProperty
(454) Rent from Electric Property
3,123,917
20
InterdepartmentalRents
(455) Interdepartmental Rents
21
OtherElectricRevenue
(456) Other Electric Revenues
(a)
165,949
22
RevenuesFromTransmissionOfElectricityOfOthers
(456.1) Revenues from Transmission of Electricity of Others
63,201,021
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
66,680,634
27
ElectricOperatingRevenues
TOTAL Electric Operating Revenues
794,794,584
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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
FOOTNOTE DATA

(a) Concept: OtherElectricRevenue
YTD Q3
Other Electric Revenue
(456)
2022
Ancillary Services:
Scheduling, System Control and Dispatch $ 1,445,573 
Regulation and Frequency Response 833,392 
Energy Imbalance (4,410,342)
Other Transmission Revenue (718,048)
Low Income Housing 1,763,882 
Steam Sales 849,423 
Sale of Materials 64,419 
Miscellaneous 5,752 
$ (165,949)

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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)
48,369,400
3
SteamPowerGenerationMaintenanceExpense
Steam Power Generation – Maintenance (510-515)
8,913,321
4
PowerProductionExpensesSteamPower
Total Power Production Expenses - Steam Power
57,282,721
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)
9,182,130
9
HydraulicPowerGenerationMaintenanceExpense
Hydraulic Power Generation – Maintenance (541-545.1)
2,098,626
10
PowerProductionExpensesHydraulicPower
Total Power Production Expenses - Hydraulic Power
11,280,756
11
RentsOtherPowerGeneration
Other Power Generation – Operation (546-550.1)
27,145,023
12
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration
Other Power Generation – Maintenance (551-554.1)
1,476,914
13
MaintenanceOfMiscellaneousOtherPowerGenerationPlant
Total Power Production Expenses - Other Power
28,621,937
14
OtherPowerSuplyExpensesAbstract
Other Power Supply Expenses
15
PurchasedPower
(555) Purchased Power
181,619,388
15.1
PowerPurchasedForStorageOperations
(555.1) Power Purchased for Storage Operations
16
SystemControlAndLoadDispatchingElectric
(556) System Control and Load Dispatching
212,728
17
OtherExpensesOtherPowerSupplyExpenses
(557) Other Expenses
34,822,124
18
OtherPowerSupplyExpense
Total Other Power Supply Expenses (line 15-17)
147,009,992
19
PowerProductionExpenses
Total Power Production Expenses (Total of lines 4, 7, 10, 13 and 18)
244,195,406
20
TransmissionExpensesAbstract
2. TRANSMISSION EXPENSES
21
TransmissionExpensesOperationAbstract
Transmission Operation Expenses
22
OperationSupervisionAndEngineeringElectricTransmissionExpenses
(560) Operation Supervision and Engineering
2,267,204
24
LoadDispatchReliability
(561.1) Load Dispatch-Reliability
737,380
25
LoadDispatchMonitorAndOperateTransmissionSystem
(561.2) Load Dispatch-Monitor and Operate Transmission System
703,209
26
LoadDispatchTransmissionServiceAndScheduling
(561.3) Load Dispatch-Transmission Service and Scheduling
990,377
27
SchedulingSystemControlAndDispatchServices
(561.4) Scheduling, System Control and Dispatch Services
28
ReliabilityPlanningAndStandardsDevelopment
(561.5) Reliability, Planning and Standards Development
69,145
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
1,339,326
32.1
OperationOfEnergyStorageEquipmentTransmissionExpense
(562.1) Operation of Energy Storage Equipment
33
OverheadLineExpense
(563) Overhead Lines Expenses
1,140,497
34
UndergroundLineExpensesTransmissionExpense
(564) Underground Lines Expenses
35
TransmissionOfElectricityByOthers
(565) Transmission of Electricity by Others
20,334,573
36
MiscellaneousTransmissionExpenses
(566) Miscellaneous Transmission Expenses
160,298
37
RentsTransmissionElectricExpense
(567) Rents
634,450
38
OperationSuppliesAndExpensesTransmissionExpense
(567.1) Operation Supplies and Expenses (Non-Major)
39
TransmissionOperationExpense
TOTAL Transmission Operation Expenses (Lines 22 - 38)
28,376,459
40
TransmissionMaintenanceAbstract
Transmission Maintenance Expenses
41
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses
(568) Maintenance Supervision and Engineering
410,100
42
MaintenanceOfStructuresTransmissionExpense
(569) Maintenance of Structures
58,083
43
MaintenanceOfComputerHardwareTransmission
(569.1) Maintenance of Computer Hardware
1,173,707
44
MaintenanceOfComputerSoftwareTransmission
(569.2) Maintenance of Computer Software
1,988
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
515,855
47.1
MaintenanceOfEnergyStorageEquipmentTransmission
(570.1) Maintenance of Energy Storage Equipment
48
MaintenanceOfOverheadLinesTransmission
(571) Maintenance of Overhead Lines
2,962,835
49
MaintenanceOfUndergroundLinesTransmission
(572) Maintenance of Underground Lines
57
50
MaintenanceOfMiscellaneousTransmissionPlant
(573) Maintenance of Miscellaneous Transmission Plant
51
MaintenanceOfTransmissionPlant
(574) Maintenance of Transmission Plant
52
TransmissionMaintenanceExpenseElectric
TOTAL Transmission Maintenance Expenses (Lines 41 – 51)
5,122,625
53
TransmissionExpenses
Total Transmission Expenses (Lines 39 and 52)
33,499,084
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
263,189
58
TransmissionRightsMarketAdministration
(575.3) Transmission Rights Market Facilitation
59
CapacityMarketAdministration
(575.4) Capacity Market Facilitation
60
AncillaryServicesMarketAdministration
(575.5) Ancillary Services Market Facilitation
75,198
61
MarketMonitoringAndCompliance
(575.6) Market Monitoring and Compliance
37,598
62
MarketFacilitationMonitoringAndComplianceServices
(575.7) Market Facilitation, Monitoring and Compliance Services
63
RegionalMarketOperationExpense
Regional Market Operation Expenses (Lines 55 - 62)
375,985
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)
375,985
72
DistributionExpensesAbstract
4. DISTRIBUTION EXPENSES
73
DistributionOperationExpensesElectric
Distribution Operation Expenses (580-589)
12,661,313
74
DistributionMaintenanceExpenseElectric
Distribution Maintenance Expenses (590-598)
14,858,427
75
DistributionExpenses
Total Distribution Expenses (Lines 73 and 74)
27,519,740


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
8,390,351
2
CustomerServiceAndInformationExpenses
(907-910) Customer Service and Information Expenses
3,362,591
3
SalesExpenses
(911-917) Sales Expenses
753,720
4
AdministrativeAndGeneralExpensesAbstract
8. ADMINISTRATIVE AND GENERAL EXPENSES
5
AdministrativeAndGeneralExpensesOperationAbstract
Operation
6
AdministrativeAndGeneralSalaries
(920) Administrative and General Salaries
23,853,619
7
OfficeSuppliesAndExpenses
(921) Office Supplies and Expenses
12,596,524
8
AdministrativeExpensesTransferredCredit
(Less) (922) Administrative Expenses Transferred-Credit
6,131,758
9
OutsideServicesEmployed
(923) Outside Services Employed
6,908,469
10
PropertyInsurance
(924) Property Insurance
2,311,566
11
InjuriesAndDamages
(925) Injuries and Damages
8,187,382
12
EmployeePensionsAndBenefits
(926) Employee Pensions and Benefits
17,104,353
13
FranchiseRequirements
(927) Franchise Requirements
14
RegulatoryCommissionExpenses
(928) Regulatory Commission Expenses
2,050,303
15
DuplicateChargesCredit
(929) (Less) Duplicate Charges-Cr.
16
GeneralAdvertisingExpenses
(930.1) General Advertising Expenses
263,942
17
MiscellaneousGeneralExpenses
(930.2) Miscellaneous General Expenses
11,152,867
18
RentsAdministrativeAndGeneralExpense
(931) Rents
844,831
19
AdministrativeAndGeneralOperationExpense
TOTAL Operation (Total of lines 6 thru 18)
79,142,098
20
AdministrativeAndGeneralExpensesMaintenanceAbstract
Maintenance
21
MaintenanceOfGeneralPlant
(935) Maintenance of General Plant
3,309,888
22
AdministrativeAndGeneralExpenses
TOTAL Administrative and General Expenses (Total of lines 19 and 21)
82,451,986


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
11,192
11,192
52,261
52,261
3
Aspen Air U.S., LLC
Talen Energy
Aspen Air Corporation
Colstrip
Billings, MT
11
14,554
14,554
66,969
66,969
4
Barretts Minerals, Inc.
Energy Keepers inc.
Barretts Minerals, Inc.
Kerr
Dillon, MT
6
7,710
7,710
42,226
42,226
5
Beartooth Electric Cooperative, Inc.
WAPA
Beartooth Electric Cooperative, Inc.
Fort Peck
Various in Montana
18
20,522
20,522
140,942
140,942
6
Benefis Health Systems
Energy Keepers inc.
Benefis Health Systems
Kerr
Various in Montana
7
9,430
9,430
52,651
52,651
7
Big Horn County Electric Coop. Inc.
WAPA
Big Horn County Electric Coop. Inc.
Various & Great Falls
Various in Montana
18
19,053
19,053
114,970
114,970
8
Bonneville Power Administration
BPA
Bonneville Power Administration
BPAT.NWMT
Various in Montana
185
232,650
232,650
1,386,865
1,386,865
9
Basin Electric Power Cooperative
Morgan Stanley, Talen & WAPA
Basin Electric Power Cooperative
Various in Montana
Various NWMT & WAUW
181
224,221
224,221
1,280,181
1,280,181
10
Basin Electric Power Cooperative
Basin Electric & WAPA
Basin Electric Power Cooperative
Crossover
Various NWMT & WAUW
15
19,589
19,589
115,763
115,763
11
CHS, Inc.
Morgan Stanley
CHS, Inc.
MATL.NWMT
Various in Montana
58
91,350
91,350
431,282
431,282
12
City of Great Falls
Energy Keepers Inc.
City of Great Falls
Kerr
Various in Montana
6
5,706
5,706
27,143
27,143
13
Talen Montana, LLC
Avista Energy
Colstrip Steam Electric Station
Colstrip
Nichols Pump Sub
10
10,171
10,171
39,214
39,214
14
Atlas Power, LLC
Portland General Electric
Atlas Power, LLC
Colstrip
Butte, MT
75
117,743
117,743
280,883
280,883
15
Phillips 66 Company
Shell Energy
Phillips 66 Company
BPAT.NWMT
Various in Montana
70
112,558
112,558
479,586
479,586
16
ExxonMobil Corporation
Talen Energy
ExxonMobil Corporation
Colstrip
Billings, MT
35
55,152
55,152
263,502
263,502
17
General Mills Operations, LLC
Talen Energy
General Mills Operations, LLC
Colstrip
Great Falls, MT
4
4,943
4,943
24,705
24,705
18
Great Falls Public Schools
Energy Keepers Inc.
Great Falls Public Schools
Kerr
Great Falls, MT
3
1,928
1,928
15,271
15,271
19
GCC Three Forks, LLC
Energy Keepers Inc.
GCC Three Forks, LLC
Kerr
Three Forks, MT
8
11,614
11,614
46,053
46,053
20
Magris Talc USA, Inc.
Energy Keepers Inc.
Magris Talc USA, Inc.
Kerr
Three Forks, MT
6
6,992
6,992
38,404
38,404
21
Suiza Dairy Group, LLC
Talen Energy
Suiza Dairy Group, LLC
Colstrip
Various in Montana
2
1,662
1,662
8,120
8,120
22
Calumet Refining, LLC
Talen Energy
Calumet Montana Refining Company, Inc.
Colstrip
Great Falls, MT
25
21,880
21,880
128,154
128,154
23
Montana Resources
Talen Energy & Energy Keepers, Inc.
Montana Resources
Colstrip & Kerr
Butte, MT
50
86,201
86,201
422,029
422,029
24
REC Silicon Company
Morgan Stanley
REC Silicon Company
Hardin
Butte, MT
117
141,440
141,440
695,624
695,624
25
Roseburg Forest Products Company
Talen Energy
Roseburg Forest Products Company
Colstrip
Missoula, MT
8
12,338
12,338
58,920
58,920
26
Sibanye-Stillwater
Energy Keepers Inc.
Stillwater Mining Company
Kerr
Various in Montana
46
65,745
65,745
325,728
325,728
27
Town of Philipsburg
Town of Philipsburg
Town of Philipsburg
Philipsburg Substation
Philipsburg, MT
107
107
965
965
28
Western Area Power Administration
WAPA
Western Area Power Administration
Crossover
Various NWMT & WAUW
4
2
2
7,207
7,207
29
Montana State University - Bozeman
WAPA
Montana State University - Bozeman
Fort Peck West
Great Falls, MT
4
3,039
3,039
19,046
19,046
30
Western Area Power Administration
WAPA
Malmstrom Air Force Base
Fort Peck West
Great Falls, MT
4
6,706
6,706
33,406
33,406
31
MONTANA POINT-TO-POINT
32
Avista Corporation
AVA
AVA
COLSTRIP
AVAT.NWMT
6,522
6,522
30,197
30,197
33
Avista Corporation
AVA
AVA
COLSTRIP
AVAT.NWMT
31,758
31,758
146,859
146,859
34
Avista Corporation
NWMT
AVA
COLSTRIP
AVAT.NWMT
744
744
3,445
3,445
35
Basin Electric Power Cooperative
AVA
PPW
AVAT.NWMT
YTP
440
440
2,037
2,037
36
Basin Electric Power Cooperative
AVA
WAPA
AVAT.NWMT
GREATFALLS
303
303
1,403
1,403
37
Basin Electric Power Cooperative
NWMT
NWMT
COLSTRIP
NWMT.SYSTEM
6
6
28
28
38
Basin Electric Power Cooperative
NWMT
PPW
COLSTRIP
YTP
3,699
3,699
17,126
17,126
39
Basin Electric Power Cooperative
NWMT
PPW
COLSTRIP
YTP
192
192
888
888
40
Basin Electric Power Cooperative
NWMT
WAPA
COLSTRIP
CROSSOVER
28
28
130
130
41
Basin Electric Power Cooperative
NWMT
WAUW
COLSTRIP
GREATFALLS
14
14
65
65
42
Basin Electric Power Cooperative
PPW
BPAT
YTP
BPAT.NWMT
450
450
2,084
2,084
43
Basin Electric Power Cooperative
PPW
NWMT
YTP
NWMT.SYSTEM
140
140
648
648
44
Basin Electric Power Cooperative
PPW
PPW
BRDY
MLCK
800
800
3,704
3,704
45
Basin Electric Power Cooperative
PPW
WAPA
BRDY
CROSSOVER
881
881
4,079
4,079
46
Basin Electric Power Cooperative
PPW
WAPA
BRDY
GREATFALLS
45
45
208
208
47
Basin Electric Power Cooperative
PPW
WAPA
YTP
CROSSOVER
9,209
9,209
42,638
42,638
48
Basin Electric Power Cooperative
PPW
WAPA
YTP
GREATFALLS
150
150
695
695
49
Basin Electric Power Cooperative
WAPA
NWMT
CROSSOVER
NWMT.SYSTEM
8,040
8,040
37,185
37,185
50
Basin Electric Power Cooperative
WAPA
PPW
CROSSOVER
YTP
10
10
46
46
51
Basin Electric Power Cooperative
WAPA
WAPA
CROSSOVER
GREATFALLS
31
68,448
68,448
312,542
312,542
52
Black Hills Power Inc.
AVA
PPW
AVAT.NWMT
YTP
25
25
116
116
53
Black Hills Power Inc.
NWMT
PPW
COLSTRIP
YTP
353
353
1,634
1,634
54
Bonneville Power Administration
AVA
NWMT
AVAT.NWMT
NWMT.SYSTEM
67
67
310
310
55
Bonneville Power Administration
BPAT
NWMT
BPAT.NWMT
NWMT.SYSTEM
3,062
3,062
14,177
14,177
56
Bonneville Power Administration
BPAT
PPW
BPAT.NWMT
YTP
1
1
5
5
57
Bonneville Power Administration
BPAT
WAPA
BPAT.NWMT
GREATFALLS
276
276
1,278
1,278
58
Bonneville Power Administration
PPW
NWMT
BRDY
NWMT.SYSTEM
638
638
2,954
2,954
59
Brookfield Renewable Trading and Marketing LP
BPAT
PPW
BPAT.NWMT
YTP
71
71
329
329
60
Brookfield Renewable Trading and Marketing LP
BPAT
WAPA
BPAT.NWMT
CROSSOVER
123
123
569
569
61
Brookfield Renewable Trading and Marketing LP
PPW
BPAT
YTP
BPAT.NWMT
50
50
232
232
62
ConocoPhillips
WAPA
BPAT
CROSSOVER
BPAT.NWMT
48
48
222
222
63
CP Energy Marketing (US) Inc.
BPAT
NWMT
BPAT.NWMT
MATL.NWMT
275
275
1,273
1,273
64
CP Energy Marketing (US) Inc.
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
5,624
5,624
26,039
26,039
65
CP Energy Marketing (US) Inc.
NWMT
PACE
MATL.NWMT
YTP
29
29
134
134
66
CP Energy Marketing (US) Inc.
PPW
BPAT
YTP
BPAT.NWMT
1,400
1,400
6,482
6,482
67
CP Energy Marketing (US) Inc.
WAPA
BPAT
CROSSOVER
BPAT.NWMT
664
664
3,074
3,074
68
CP Energy Marketing (US) Inc.
WAPA
PPW
CROSSOVER
JEFF
2
2
9
9
69
CP Energy Marketing (US) Inc.
WAPA
PPW
CROSSOVER
YTP
481
481
2,227
2,227
70
Cycle Power Partners, LLC
NWMT
PACE
HORSESHOE
BRDY
64
64
296
296
71
Cycle Power Partners, LLC
NWMT
PACE
HORSESHOE
JEFF
1,203
1,203
5,570
5,570
72
Dynasty Power Inc.
AVA
PPW
AVAT.NWMT
YTP
855
855
3,959
3,959
73
Dynasty Power Inc.
AVA
WAPA
AVAT.NWMT
CROSSOVER
488
488
2,259
2,259
74
Dynasty Power Inc.
BPAT
PPW
BPAT.NWMT
YTP
19,078
19,078
88,158
88,158
75
Dynasty Power Inc.
BPAT
WAPA
BPAT.NWMT
CROSSOVER
675
675
3,125
3,125
76
Dynasty Power Inc.
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
1,822
1,822
8,436
8,436
77
Dynasty Power Inc.
PPW
BPAT
YTP
BPAT.NWMT
4,384
4,384
20,298
20,298
78
Dynasty Power Inc.
PPW
BPAT
YTP
BPAT.NWMT
6,864
6,864
31,746
31,746
79
Dynasty Power Inc.
PPW
PPW
YTP
BRDY
53
53
245
245
80
Dynasty Power Inc.
WAPA
BPAT
CROSSOVER
BPAT.NWMT
21,689
21,689
100,420
100,420
81
Dynasty Power Inc.
WAPA
PPW
CROSSOVER
YTP
648
648
3,000
3,000
82
EDF Trading North America, LLC
AVA
AVA
COLSTRIP
AVAT.NWMT
182
182
843
843
83
EDF Trading North America, LLC
AVA
NWMT
AVAT.NWMT
NWMT.SYSTEM
602
602
2,784
2,784
84
EDF Trading North America, LLC
BPAT
NWMT
BPAT.NWMT
COLSTRIP
232
232
1,074
1,074
85
EDF Trading North America, LLC
BPAT
NWMT
BPAT.NWMT
GTFALLSNWMT
352
352
1,630
1,630
86
EDF Trading North America, LLC
BPAT
NWMT
BPAT.NWMT
NWMT.SYSTEM
2,200
2,200
10,186
10,186
87
EDF Trading North America, LLC
NWMT
AVA
COLSTRIP
AVAT.NWMT
14
14
65
65
88
EDF Trading North America, LLC
NWMT
AVA
COLSTRIP
AVAT.NWMT
27,240
27,240
123,185
123,185
89
EDF Trading North America, LLC
NWMT
BPAT
CANYONFERRY
BPAT.NWMT
20
20
93
93
90
EDF Trading North America, LLC
NWMT
BPAT
COLSTRIP
BPAT.NWMT
7,850
7,850
36,346
36,346
91
EDF Trading North America, LLC
NWMT
BPAT
COLSTRIP
BPAT.NWMT
13,510
13,510
61,515
61,515
92
EDF Trading North America, LLC
NWMT
NWMT
BASINCREEK
NWMT.SYSTEM
110
110
509
509
93
EDF Trading North America, LLC
NWMT
NWMT
COLSTRIP
COLSTRIP
512
512
2,371
2,371
94
EDF Trading North America, LLC
NWMT
NWMT
COLSTRIP
NWMT.SYSTEM
48
48
222
222
95
EDF Trading North America, LLC
NWMT
NWMT
HARDIN
NWMT.SYSTEM
10
10
46
46
96
EDF Trading North America, LLC
NWMT
PPW
COLSTRIP
YTP
2,540
2,540
11,760
11,760
97
EDF Trading North America, LLC
PPW
NWMT
YTP
NWMT.SYSTEM
210
210
972
972
98
Energy Keepers FIP
NWMT
BPAT
KERR
BPAT.NWMT
8
17,868
17,868
44,193
44,193
99
Energy Keepers Inc.
AVA
BPAT
AVAT.NWMT
BPAT.NWMT
16
16
74
74
100
Energy Keepers Inc.
AVA
BPAT
AVAT.NWMT
BPAT.NWMT
336
336
1,554
1,554
101
Energy Keepers Inc.
AVA
PPW
AVAT.NWMT
YTP
69,625
69,625
315,818
315,818
102
Energy Keepers Inc.
NWMT
AVA
KERR
AVAT.NWMT
141
141
653
653
103
Energy Keepers Inc.
NWMT
AVA
KERR
AVAT.NWMT
312
312
1,443
1,443
104
Energy Keepers Inc.
NWMT
BPA
BGI
BPAT.NWMT
80
80
370
370
105
Energy Keepers Inc.
NWMT
BPAT
KERR
BPAT.NWMT
40
88,320
88,320
403,280
403,280
106
Energy Keepers Inc.
NWMT
BPAT
COLSTRIP
BPAT.NWMT
512
512
2,371
2,371
107
Energy Keepers Inc.
NWMT
BPAT
HOLTER
BPAT.NWMT
40
40
185
185
108
Energy Keepers Inc.
NWMT
BPAT
JUDITHGAP
BPAT.NWMT
375
375
1,736
1,736
109
Energy Keepers Inc.
NWMT
BPAT
KERR
BPAT.NWMT
1,152
1,152
5,334
5,334
110
Energy Keepers Inc.
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
50
50
232
232
111
Energy Keepers Inc.
NWMT
BPAT
STILLWIND
BPAT.NWMT
80
80
370
370
112
Energy Keepers Inc.
NWMT
BPAT
TFALLS
BPAT.NWMT
200
200
926
926
113
Energy Keepers Inc.
NWMT
BPAT
COLSTRIP
BPAT.NWMT
1,104
1,104
5,106
5,106
114
Energy Keepers Inc.
NWMT
BPAT
KERR
BPAT.NWMT
9,252
9,252
43,218
43,218
115
Energy Keepers Inc.
NWMT
PACE
KERR
BRDY
50
110,400
110,400
504,100
504,100
116
Energy Keepers Inc.
NWMT
PACE
KERR
ANTE
25
25
116
116
117
Energy Keepers Inc.
NWMT
PACE
KERR
BRDY
24
24
111
111
118
Energy Keepers Inc.
NWMT
PACE
KERR
YTP
21
21
97
97
119
Energy Keepers Inc.
NWMT
PACE
KERR
YTP
13,628
13,628
62,877
62,877
120
Energy Keepers Inc.
NWMT
PPW
COLSTRIP
YTP
6,864
6,864
31,720
31,720
121
Energy Keepers Inc.
NWMT
WAUW
MATL.NWMT
GREATFALLS
11,704
11,704
53,776
53,776
122
Energy Keepers Inc.
PPW
BPAT
YTP
BPAT.NWMT
1,248
1,248
5,772
5,772
123
Energy Keepers Inc.
PPW
NWMT
YTP
GTFALLSNWMT
24
24
111
111
124
Guzman Energy, LLC
AVA
PPW
AVAT.NWMT
BRDY
600
600
2,775
2,775
125
Guzman Energy, LLC
AVA
PPW
AVAT.NWMT
YTP
540
540
2,500
2,500
126
Guzman Energy, LLC
AVA
PPW
AVAT.NWMT
YTP
66,384
66,384
303,776
303,776
127
Guzman Energy, LLC
BPAT
PPW
BPAT.NWMT
YTP
5
5
23
23
128
Guzman Energy, LLC
BPAT
PPW
BPAT.NWMT
YTP
37,225
37,225
168,050
168,050
129
Guzman Energy, LLC
NWMT
PPW
COLSTRIP
YTP
5
5
23
23
130
Guzman Energy, LLC
PPW
AVA
YTP
AVAT.NWMT
430
430
1,990
1,990
131
Guzman Energy, LLC
PPW
AVA
YTP
AVAT.NWMT
2,423
2,423
11,211
11,211
132
Guzman Energy, LLC
PPW
BPAT
YTP
BPAT.NWMT
1,699
1,699
7,866
7,866
133
Guzman Energy, LLC
PPW
BPAT
YTP
BPAT.NWMT
18,096
18,096
83,619
83,619
134
Guzman Energy, LLC
PPW
PPW
BRDY
YTP
17
17
79
79
135
Idaho Power Company
PPW
IPCO
JEFF
TNDY
240
240
1,110
1,110
136
Macquarie Energy, LLC
AVA
PPW
AVAT.NWMT
BRDY
75
75
137
Macquarie Energy, LLC
AVA
PPW
AVAT.NWMT
YTP
111
111
514
514
138
Macquarie Energy, LLC
AVA
PPW
AVAT.NWMT
YTP
6,000
6,000
27,750
27,750
139
Macquarie Energy, LLC
AVA
WAPA
AVAT.NWMT
CROSSOVER
9,288
9,288
42,911
42,911
140
Macquarie Energy, LLC
AVA
WAPA
AVAT.NWMT
CROSSOVER
12,672
12,672
58,540
58,540
141
Macquarie Energy, LLC
NWMT
AVA
HOLTER
AVAT.NWMT
975
975
4,514
4,514
142
Macquarie Energy, LLC
NWMT
AVA
TFALLS
AVAT.NWMT
1,253
1,253
5,801
5,801
143
Macquarie Energy, LLC
NWMT
AVA
CANYONFERRY
AVAT.NWMT
600
600
2,775
2,775
144
Macquarie Energy, LLC
NWMT
BPAT
HOLTER
BPAT.NWMT
4,800
4,800
22,221
22,221
145
Macquarie Energy, LLC
NWMT
BPAT
TFALLS
BPAT.NWMT
4,706
4,706
21,786
21,786
146
Macquarie Energy, LLC
NWMT
BPAT
CANYONFERRY
BPAT.NWMT
1,200
1,200
5,550
5,550
147
Macquarie Energy, LLC
NWMT
BPAT
HOLTER
BPAT.NWMT
1,200
1,200
5,550
5,550
148
Macquarie Energy, LLC
NWMT
BPAT
TFALLS
BPAT.NWMT
1,200
1,200
5,550
5,550
149
Macquarie Energy, LLC
NWMT
PPW
COLSTRIP
YTP
855
855
3,959
3,959
150
Macquarie Energy, LLC
NWMT
PPW
COLSTRIP
YTP
16,800
16,800
77,600
77,600
151
Macquarie Energy, LLC
NWMT
WAPA
COLSTRIP
CROSSOVER
2
2
9
9
152
Macquarie Energy, LLC
NWMT
WAPA
COLSTRIP
CROSSOVER
3,504
3,504
16,206
16,206
153
Macquarie Energy, LLC
PPW
AVA
YTP
AVAT.NWMT
6,041
6,041
27,946
27,946
154
Macquarie Energy, LLC
PPW
AVA
YTP
AVAT.NWMT
8,974
8,974
41,729
41,729
155
Macquarie Energy, LLC
PPW
BPAT
YTP
BPAT.NWMT
3,003
3,003
13,898
13,898
156
Macquarie Energy, LLC
PPW
BPAT
YTP
BPAT.NWMT
31,840
31,840
147,555
147,555
157
Macquarie Energy, LLC
WAPA
BPAT
CROSSOVER
BPAT.NWMT
824
824
3,815
3,815
158
Macquarie Energy, LLC
WAPA
PPW
CROSSOVER
YTP
1,625
1,625
7,518
7,518
159
MAG Energy Solutions
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
1,085
1,085
5,024
5,024
160
MAG Energy Solutions
WAPA
BPAT
CROSSOVER
BPAT.NWMT
136
136
630
630
161
Mercuria Energy America, LLC
AVA
PPW
AVAT.NWMT
YTP
69,624
69,624
316,011
316,011
162
Mercuria Energy America, LLC
BPAT
PPW
BPAT.NWMT
YTP
614
614
2,843
2,843
163
Mercuria Energy America, LLC
PPW
BPAT
YTP
BPAT.NWMT
26
26
120
120
164
Morgan Stanley Capital Group, Inc.
AVA
AVA
COLSTRIP
AVAT.NWMT
450
450
2,084
2,084
165
Morgan Stanley Capital Group, Inc.
AVA
GWA
AVAT.NWMT
GLWND1
56
56
259
259
166
Morgan Stanley Capital Group, Inc.
AVA
GWA
AVAT.NWMT
GLWND2
85
85
394
394
167
Morgan Stanley Capital Group, Inc.
AVA
NWMT
AVAT.NWMT
MATL.NWMT
44,426
44,426
205,497
205,497
168
Morgan Stanley Capital Group, Inc.
AVA
NWMT
AVAT.NWMT
MATL.NWMT
58,728
58,728
267,230
267,230
169
Morgan Stanley Capital Group, Inc.
AVA
PPW
AVAT.NWMT
BRDY
110,350
110,350
504,150
504,150
170
Morgan Stanley Capital Group, Inc.
AVA
PPW
AVAT.NWMT
YTP
106
106
491
491
171
Morgan Stanley Capital Group, Inc.
BPAT
GWA
BPAT.NWMT
GLWND1
559
559
2,588
2,588
172
Morgan Stanley Capital Group, Inc.
BPAT
GWA
BPAT.NWMT
GLWND2
228
228
1,056
1,056
173
Morgan Stanley Capital Group, Inc.
BPAT
NWMT
BPAT.NWMT
MATL.NWMT
124,116
124,116
573,466
573,466
174
Morgan Stanley Capital Group, Inc.
BPAT
NWMT
BPAT.NWMT
NWMT.SYSTEM
157
157
727
727
175
Morgan Stanley Capital Group, Inc.
BPAT
NWMT
BPAT.NWMT
COLSTRIP
552
552
2,553
2,553
176
Morgan Stanley Capital Group, Inc.
BPAT
NWMT
BPAT.NWMT
MATL.NWMT
6,744
6,744
31,191
31,191
177
Morgan Stanley Capital Group, Inc.
BPAT
PPW
BPAT.NWMT
BRDY
4
4
19
19
178
Morgan Stanley Capital Group, Inc.
BPAT
PPW
BPAT.NWMT
JEFF
685
685
3,169
3,169
179
Morgan Stanley Capital Group, Inc.
BPAT
PPW
BPAT.NWMT
JEFF
19,872
19,872
90,747
90,747
180
Morgan Stanley Capital Group, Inc.
BPAT
WAPA
BPAT.NWMT
CROSSOVER
450
450
2,084
2,084
181
Morgan Stanley Capital Group, Inc.
GWA
AVA
GLWND1
AVAT.NWMT
1,448
1,448
6,768
6,768
182
Morgan Stanley Capital Group, Inc.
GWA
AVA
GLWND2
AVAT.NWMT
1,179
1,179
5,503
5,503
183
Morgan Stanley Capital Group, Inc.
GWA
BPAT
GLWND1
BPAT.NWMT
25,317
25,317
117,148
117,148
184
Morgan Stanley Capital Group, Inc.
GWA
BPAT
GLWND2
BPAT.NWMT
14,654
14,654
67,804
67,804
185
Morgan Stanley Capital Group, Inc.
GWA
BPAT
GLWND1
BPAT.NWMT
33,120
33,120
151,245
151,245
186
Morgan Stanley Capital Group, Inc.
GWA
BPAT
GLWND2
BPAT.NWMT
22,080
22,080
100,830
100,830
187
Morgan Stanley Capital Group, Inc.
GWA
GWA
GLWND1
GLWND2
11,040
11,040
50,415
50,415
188
Morgan Stanley Capital Group, Inc.
GWA
NWMT
GLWND1
MATL.NWMT
2,643
2,643
12,237
12,237
189
Morgan Stanley Capital Group, Inc.
GWA
NWMT
GLWND2
MATL.NWMT
659
659
3,051
3,051
190
Morgan Stanley Capital Group, Inc.
GWA
NWMT
GLWND2
NWMT.SYSTEM
2
2
9
9
191
Morgan Stanley Capital Group, Inc.
GWA
NWMT
GLWND2
NWMT.SYSTEM
13,248
13,248
60,498
60,498
192
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND1
BRDY
335
335
1,551
1,551
193
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND1
JEFF
160
160
741
741
194
Morgan Stanley Capital Group, Inc.
GWA
PPW
GLWND2
BRDY
35
35
162
162
195
Morgan Stanley Capital Group, Inc.
GWA
WAPA
GLWND1
CROSSOVER
10
10
46
46
196
Morgan Stanley Capital Group, Inc.
NWMT
AVA
HARDIN
AVAT.NWMT
560
560
2,593
2,593
197
Morgan Stanley Capital Group, Inc.
NWMT
AVA
KERR
AVAT.NWMT
128
128
593
593
198
Morgan Stanley Capital Group, Inc.
NWMT
AVA
MATL.NWMT
AVAT.NWMT
5,103
5,103
23,609
23,609
199
Morgan Stanley Capital Group, Inc.
NWMT
AVA
MATL.NWMT
AVAT.NWMT
6,624
6,624
30,249
30,249
200
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
COLSTRIP
BPAT.NWMT
856
856
3,960
3,960
201
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
HARDIN
BPAT.NWMT
4,516
4,516
20,903
20,903
202
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
KERR
BPAT.NWMT
384
384
1,778
1,778
203
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
37,906
37,906
175,440
175,440
204
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
COLSTRIP
BPAT.NWMT
600
600
2,775
2,775
205
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
HARDIN
BPAT.NWMT
3,816
3,816
17,649
17,649
206
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
KERR
BPAT.NWMT
1,536
1,536
7,104
7,104
207
Morgan Stanley Capital Group, Inc.
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
55,200
55,200
252,075
252,075
208
Morgan Stanley Capital Group, Inc.
NWMT
GWA
COLSTRIP
GLWND1
6
6
28
28
209
Morgan Stanley Capital Group, Inc.
NWMT
GWA
HARDIN
GLWND1
6
6
28
28
210
Morgan Stanley Capital Group, Inc.
NWMT
GWA
MATL.NWMT
GLWND1
328
328
1,519
1,519
211
Morgan Stanley Capital Group, Inc.
NWMT
GWA
MATL.NWMT
GLWND2
16
16
74
74
212
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
COLSTRIP
MATL.NWMT
18,457
18,457
85,412
85,412
213
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
HARDIN
MATL.NWMT
20,608
20,608
95,355
95,355
214
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
HARDIN
NWMT.SYSTEM
24
24
111
111
215
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
COLSTRIP
MATL.NWMT
18,122
18,122
83,583
83,583
216
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
HARDIN
MATL.NWMT
43,393
43,393
200,448
200,448
217
Morgan Stanley Capital Group, Inc.
NWMT
NWMT
KERR
MATL.NWMT
816
816
3,774
3,774
218
Morgan Stanley Capital Group, Inc.
NWMT
PACE
MATL.NWMT
BRDY
1,500
1,500
6,945
6,945
219
Morgan Stanley Capital Group, Inc.
NWMT
PACE
MATL.NWMT
JEFF
124
124
574
574
220
Morgan Stanley Capital Group, Inc.
NWMT
PACE
MATL.NWMT
YTP
24
24
111
111
221
Morgan Stanley Capital Group, Inc.
PACE
NWMT
BRDY
MATL.NWMT
736
736
3,408
3,408
222
Morgan Stanley Capital Group, Inc.
WAPA
AVA
GREATFALLS
AVAT.NWMT
259
259
1,199
1,199
223
Morgan Stanley Capital Group, Inc.
WAPA
BPAT
GREATFALLS
BPAT.NWMT
2,721
2,721
12,598
12,598
224
Morgan Stanley Capital Group, Inc.
WAUW
NWMT
GREATFALLS
MATL.NWMT
684
684
3,167
3,167
225
PacifiCorp
BPAT
PPW
BPAT.NWMT
YTP
117,024
117,024
534,399
534,399
226
PacifiCorp
NWMT
PPW
COLSTRIP
YTP
2,325
2,325
10,765
10,765
227
PacifiCorp
NWMT
PPW
COLSTRIP
YTP
127,658
127,658
587,194
587,194
228
PacifiCorp
PPW
PPW
BRDY
YTP
19,883
19,883
91,568
91,568
229
Portland General Electric Company
NWMT
BPAT
COLSTRIP
BPAT.NWMT
2,885
2,885
13,358
13,358
230
Portland General Electric Company
NWMT
PPW
COLSTRIP
JEFF
25
25
116
116
231
Powerex Corporation
AVA
WAPA
AVAT.NWMT
CROSSOVER
976
976
4,519
4,519
232
Powerex Corporation
BPAT
PPW
BPAT.NWMT
BRDY
76
167,808
167,808
766,232
766,232
233
Powerex Corporation
BPAT
PPW
BPAT.NWMT
JEFF
71
156,768
156,768
715,822
715,822
234
Powerex Corporation
BPAT
PPW
BPAT.NWMT
YTP
1,455
1,455
6,737
6,737
235
Powerex Corporation
BPAT
WAPA
BPAT.NWMT
CROSSOVER
2,121
2,121
9,820
9,820
236
Powerex Corporation
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
1,044
1,044
4,834
4,834
237
Powerex Corporation
PPW
BPAT
YTP
BPAT.NWMT
703
703
3,255
3,255
238
Powerex Corporation
PPW
WAPA
JEFF
CROSSOVER
1,055
1,055
4,885
4,885
239
Powerex Corporation
PPW
WAPA
YTP
CROSSOVER
1,136
1,136
5,260
5,260
240
Powerex Corporation
WAPA
BPAT
CROSSOVER
BPAT.NWMT
242
242
1,120
1,120
241
Puget Sound Energy Marketing
NWMT
BPAT
COLSTRIP
BPAT.NWMT
13,047
13,047
60,365
60,365
242
Puget Sound Energy Marketing
NWMT
BPAT
COLSTRIP
BPAT.NWMT
9,624
9,624
44,489
44,489
243
Rainbow Electric Marketing Corp.
AVA
PPW
AVAT.NWMT
YTP
110
110
509
509
244
Rainbow Electric Marketing Corp.
AVA
PPW
AVAT.NWMT
YTP
37,368
37,368
168,827
168,827
245
Rainbow Electric Marketing Corp.
AVA
WAPA
AVAT.NWMT
CROSSOVER
1,302
1,302
6,028
6,028
246
Rainbow Electric Marketing Corp.
BPAT
PPW
BPAT.NWMT
YTP
1,009
1,009
4,672
4,672
247
Rainbow Electric Marketing Corp.
BPAT
WAPA
BPAT.NWMT
CROSSOVER
721
721
3,338
3,338
248
Rainbow Electric Marketing Corp.
NWMT
PPW
COLSTRIP
YTP
960
960
4,440
4,440
249
Rainbow Electric Marketing Corp.
NWMT
WAUW
NWMTIMBALANC
CROSSOVER
2
2
9
9
250
Rainbow Electric Marketing Corp.
PPW
AVA
YTP
AVAT.NWMT
70
70
324
324
251
Rainbow Electric Marketing Corp.
PPW
BPAT
YTP
BPAT.NWMT
14,771
14,771
68,390
68,390
252
Rainbow Electric Marketing Corp.
PPW
BPAT
YTP
BPAT.NWMT
240
240
1,110
1,110
253
Rainbow Electric Marketing Corp.
PPW
WAPA
BRDY
GREATFALLS
216
216
1,000
1,000
254
Rainbow Electric Marketing Corp.
PPW
WAPA
YTP
CROSSOVER
2,122
2,122
9,825
9,825
255
Rainbow Electric Marketing Corp.
WAPA
AVA
CROSSOVER
AVAT.NWMT
225
225
1,042
1,042
256
Rainbow Electric Marketing Corp.
WAPA
BPAT
CROSSOVER
BPAT.NWMT
7,714
7,714
35,716
35,716
257
Rainbow Electric Marketing Corp.
WAPA
PPW
CROSSOVER
YTP
1,286
1,286
5,954
5,954
258
Shell Energy North America
BPAT
NWMT
BPAT.NWMT
GTFALLSNWMT
3
3
14
14
259
Shell Energy North America
BPAT
PPW
BPAT.NWMT
BRDY
51
51
236
236
260
Shell Energy North America
BPAT
PPW
BPAT.NWMT
YTP
178
178
824
824
261
Shell Energy North America
BPAT
WAPA
BPAT.NWMT
CROSSOVER
208
208
963
963
262
Shell Energy North America
NWMT
AVA
HOLTER
AVAT.NWMT
601
601
2,783
2,783
263
Shell Energy North America
NWMT
AVA
TFALLS
AVAT.NWMT
601
601
2,783
2,783
264
Shell Energy North America
NWMT
AVA
HOLTER
AVAT.NWMT
600
600
2,775
2,775
265
Shell Energy North America
NWMT
AVA
TFALLS
AVAT.NWMT
600
600
2,775
2,775
266
Shell Energy North America
PPW
AVA
YTP
AVAT.NWMT
6,147
6,147
28,461
28,461
267
Shell Energy North America
PPW
AVA
YTP
AVAT.NWMT
11,664
11,664
53,946
53,946
268
Shell Energy North America
PPW
BPAT
YTP
BPAT.NWMT
9,984
9,984
46,226
46,226
269
Shell Energy North America
PPW
BPAT
YTP
BPAT.NWMT
504
504
2,331
2,331
270
Shell Energy North America
PPW
PPW
BRDY
MLCK
171
171
792
792
271
Shell Energy North America
PPW
PPW
YTP
BRDY
1,139
1,139
5,271
5,271
272
Shell Energy North America
WAPA
AVA
CROSSOVER
AVAT.NWMT
2,299
2,299
10,644
10,644
273
Shell Energy North America
WAPA
AVA
CROSSOVER
AVAT.NWMT
1,200
1,200
5,550
5,550
274
Shell Energy North America
WAPA
BPAT
CROSSOVER
BPAT.NWMT
4,355
4,355
20,164
20,164
275
Shell Energy North America
WAPA
PPW
CROSSOVER
YTP
40
40
185
185
276
TEC Energy Inc.
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
93
93
431
431
277
The Energy Authority
AVA
BPAT
AVAT.NWMT
BPAT.NWMT
7
7
32
32
278
The Energy Authority
AVA
PPW
AVAT.NWMT
YTP
2,405
2,405
11,135
11,135
279
The Energy Authority
AVA
WAPA
AVAT.NWMT
CROSSOVER
150
150
695
695
280
The Energy Authority
BPAT
PPW
BPAT.NWMT
YTP
5,318
5,318
24,622
24,622
281
The Energy Authority
BPAT
WAPA
BPAT.NWMT
CROSSOVER
2,973
2,973
13,765
13,765
282
The Energy Authority
NWMT
PACE
TFALLS
YTP
481
481
2,227
2,227
283
The Energy Authority
NWMT
PPW
COLSTRIP
YTP
2,962
2,962
13,714
13,714
284
The Energy Authority
PPW
AVA
YTP
AVAT.NWMT
631
631
2,922
2,922
285
The Energy Authority
PPW
BPAT
YTP
BPAT.NWMT
21,405
21,405
99,102
99,102
286
The Energy Authority
PPW
PPW
YTP
BRDY
25
25
116
116
287
The Energy Authority
WAPA
BPAT
CROSSOVER
BPAT.NWMT
5,877
5,877
27,211
27,211
288
The Energy Authority
WAPA
PPW
CROSSOVER
BRDY
50
50
232
232
289
The Energy Authority
WAPA
PPW
CROSSOVER
YTP
30
30
139
139
290
Transalta Energy Marketing (US) Inc.
BPAT
PPW
BPAT.NWMT
YTP
315
315
1,458
1,458
291
Transalta Energy Marketing (US) Inc.
BPAT
WAPA
BPAT.NWMT
CROSSOVER
1,006
1,006
4,658
4,658
292
Transalta Energy Marketing (US) Inc.
NWMT
BPAT
MATL.NWMT
BPAT.NWMT
21,178
21,178
98,027
98,027
293
Transalta Energy Marketing (US) Inc.
NWMT
WAUW
MATL.NWMT
CROSSOVER
138
138
639
639
294
Transalta Energy Marketing (US) Inc.
PPW
BPAT
YTP
BPAT.NWMT
6,102
6,102
28,244
28,244
295
Transalta Energy Marketing (US) Inc.
WAPA
BPAT
CROSSOVER
BPAT.NWMT
9,857
9,857
45,638
45,638
296
Transalta Energy Marketing (US) Inc.
WAPA
BPAT
CROSSOVER
BPAT.NWMT
312
312
1,443
1,443
297
Uniper Global Commodities North America LLC
BPAT
PPW
BPAT.NWMT
YTP
361
361
1,671
1,671
298
Vitol Inc.
AVA
PPW
AVAT.NWMT
BRDY
114,434
114,434
517,075
517,075
299
Western Area Power Administration
NWMT
WAPA
CANYONFERRY
CROSSOVER
58,994
58,994
273,052
273,052
300
Western Area Power Administration
WAPA
NWMT
CROSSOVER
NWMT.SYSTEM
153
153
708
708
301
Western Area Power Administration
WAPA
NWMT
GREATFALLS
NWMT.SYSTEM
4,368
4,368
20,111
20,111
302
Western Area Power Administration
WAPA
WAPA
GREATFALLS
CROSSOVER
51,274
51,274
236,968
236,968
303
Western Area Power Administration
WAPA
WAPA
CROSSOVER
GREATFALLS
22,080
22,080
100,830
100,830
304
SOUTH DAKOTA
305
BRYANT, CITY OF
WAPA
BRYANT
HURON 115 KV BUS
BRYANT 25 KV
1,124
1,124
8,949
8,949
306
GROTON, CITY OF
WAPA
GROTON
HURON 115 KV BUS
GROTON 69 KV
4,078
4,078
281
281
307
LANGFORD, CITY OF
WAPA
LANGFORD
HURON 115 KV BUS
LANGFORD 12.5 KV
753
753
6,520
6,520
308
Southwest Power Pool (SPP)
SPP
Various
Various
Various
0
(a)
63,998
63,998
309
Southwest Power Pool (SPP)
SPP
Various
Various
Various
(b)
22,422
22,422
310
Southwest Power Pool (SPP)
SPP
Various
Various
Various
0
(c)
1,467,489
1,467,489
311
Southwest Power Pool (SPP)
SPP
Various
Various
Various
(d)
32,900
32,900
312
Rounding
1
1
1
5
4
35 TOTAL
1,259
4,016,543
4,016,543
9,359,990
9,571,185
1,586,809
20,517,984


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
(d) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Firm and Non-Firm Point to Point Transmission Service

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
9,172
9,172
13,491
13,491
3
Bonneville Power Admin
(a)
913,754
913,754
4
Southwester Power Pool (MT)
29,732
29,732
343,269
343,269
5
Supply:
6
Avista
498
498
4,445
4,445
7
Bonneville Power Admin
111,160
111,160
320,867
320,867
8
Seattle City Light
1,584
1,584
2,338
2,338
9
SOUTH DAKOTA
10
East River
7,096
7,096
11
Southwest Power Pool (SD)
5,058,397
5,058,397
TOTAL
152,146
152,146
5,422,253
327,650
913,754
6,663,657


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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
1,156,943
1,156,943
2
Steam Production Plant
5,588,980
5,588,980
3
Nuclear Production Plant
4
Hydraulic Production Plant-Conventional
7,589,096
7,589,096
5
Hydraulic Production Plant-Pumped Storage
6
Other Production Plant
13,790,930
2,652
13,793,582
7
Transmission Plant
20,827,067
377,173
21,204,240
8
Distribution Plant
45,084,553
19,034
45,065,519
9
General Plant
7,406,807
7,406,807
10
Common Plant-Electric
4,003,157
3,946,577
7,949,734
11
TOTAL
104,290,590
5,464,311
109,754,901


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
35,471,122
84,038,633
2.1 Net Purchases (Account 555.1)
3 Net Sales (Account 447)
26,809,262
34,880,516
87,574,785
4 Transmission Rights
5 Ancillary Services
24,860
25,015
25,323
6 Other Items (list separately)
7
Day Ahead & Real Time Admin
87,009
87,550
88,630
8
Market Monitoring & Compliance
12,430
12,507
12,661
46 TOTAL
56,422,453
70,476,710
171,740,032


Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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 July 577,833  72,109  2,278  29 17
2 August 704,156  60,394  2,339  1 17
3 September 690,234  83,980  2,088  7 16
4 Total for Quarter 1,972,223  216,483 


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 July 97,446  —  248  18 16
2 August 161,120  —  238  5 16
3 September 179,600  —  267  1 17
4 Total for Quarter 438,166  — 

Name of Respondent:

NorthWestern Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
1,621
14
9
1,059
635
250
12
2,997
6
May
1,450
20
9
1,056
589
250
12
1,872
7
June
1,791
28
17
1,041
688
275
12
3,033
8
Total for Quarter 2
3,156
1,912
775
36
7,902
9
July
1,991
29
17
1,041
696
275
12
3,104
10
August
2,052
1
17
1,051
702
275
12
2,764
11
September
1,813
7
16
1,064
600
275
0
5,593
12
Total for Quarter 3
3,156
1,998
825
24
11,461
13
October
14
November
15
December
16
Total for Quarter 4
0
0
0
0
0
17
Total
9,452
6,070
1,834
96
33,371
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:

09/30/2022
Year/Period of Report

End of:
2022
/
Q3
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
251
14
10
263
12
275
6
May
281
12
16
291
10
301
7
June
302
20
16
316
14
330
8
Total for Quarter 2
870
36
906
9
July
248
18
16
258
10
268
10
August
238
5
16
250
12
262
11
September
267
1
17
281
14
295
12
Total for Quarter 3
789
36
825
13
October
0
14
November
0
15
December
0
16
Total for Quarter 4
17
Total Year to Date/Year
2,516
113
2,629