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C000530 ferc:TransmissionStudiesMember AF1-323 , 54430.14 2021-01-012021-12-31 C000530 Estimated , -101 , -7905 2021-01-012021-12-31 C000530 341 Ceredo Plant, 1652000, 0.0127 2021-01-012021-12-31 C000530 Administrative and General Expenses - Operation, AEPSC , 4529117.84 2021-01-012021-12-31 C000530 SGS-PA- Small Gen Ser - PA , 45689 , 4492767 2021-01-012021-12-31 C000530 EAST HUNTINGTON - WV, Transmission, , 34.5, 12, , 9.38,  2021-12-31 C000530 345 Dresden - VA AFUDC, 477000, 0.1951 2021-01-012021-12-31 C000530 ARCHER CREEK - VA, Distribution, , 69, 12, , 10.5,  2021-12-31 C000530 Corporate Contributions and Memberships 2021-01-012021-12-31 C000530 PJM - #AE2-280  , 154449.34 2021-01-012021-12-31 C000530 APCO: 2020 - 2022 RBB Graysonferc:ElectricUtilityMember 2021-12-31 C000530 MIDDLE BURNING CREEK - WV, Distribution, , 34.5, 12, , 5,  2021-12-31 C000530 Other Deferred Credits 2021-12-31 C000530 UNITED LIGHT & POWER COMPANY, RQ, 151 2021-01-012021-12-31 C000530 CATAWBA - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0508 CLOVERDALE EAST, CLOVERDALE TIE LINE NO 2, 1, 0, 1, 2-1926.9KCM ACSR/, 0, 0 2021-01-012021-12-31 C000530 HILLMAN HIGHWAY - VA, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 PJM - #AG1-123  , 2484.24ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 CABELL - WV, Distribution, , 138, 36.2, , 30,  2021-01-012021-12-31 C000530 HILL - VA, Transmission, , 138, 13.09, , 8.4,  2021-01-012021-12-31 C000530 315 - Mountaineer, 76277000, P60Y, 0.0187 2021-01-012021-12-31 C000530 0322 JOSHUA FALLS, VA, REUSENS A&B, VA, 3, 7, 2, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SALTVILLE - VA, Transmission, , 138, 69, 34.5, 56,  2021-01-012021-12-31 C000530 Unemployment Tax, WV,  , 194703 2020-12-31 C000530 Byllesby Buck Hydro Project #2514 - Proportion of cost of administering the Federal Water Power Act 2021-01-012021-12-31 C000530 SPORN 138KV - WV, Transmission, , 138, 13.09, , 20,  2021-12-31 C000530 VA Renewable Energy Portfolio Standard - VA SCC Case No. PUE-2009-00038 2020-12-31 C000530 WV Deferred Rate Case Expenses - WVPSC Case #18-0646-E-42T - Amortization Period: 03/2019 - 02/2022 2021-12-31 C000530 ferc:ElectricUtilityMember Accrued Book Removal Costs 2021-12-31 C000530 ferc:NonUtilityMember Others 2021-12-31 C000530 ferc:ElectricUtilityMember Berry Hill Station 2021-12-31 C000530 Income Tax, MI, 2020 , 2021-01-012021-12-31 C000530 0013 LOGAN, WV, WYOMING #1-B, WV, 3, 22, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ROBINSON - WV, Distribution, , 69, 12, , 10.4,  2021-12-31 C000530 WARD HOLLOW - WV, Transmission, , 46, 13.8, , 40,  2021-12-31 C000530 BECKLEY - WV, Distribution, , 46, 12, , 40,  2021-12-31 C000530 214, d, 46 2021-01-012021-12-31 C000530 UNITED FUEL GAS COMPANY - WV, Distribution, , 69, 4, , 6.25,  2021-12-31 C000530 367 - WV, 117016000, 0.0205 2021-01-012021-12-31 C000530 AMOS 765KV - WV, Transmission, , 765, 345, 34.5, ,  2021-12-31 C000530 STUART - VA, Distribution, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 HURRICANE - WV, Distribution, , 69, 12, , 25,  2021-01-012021-12-31 C000530 FERC Formula Rates Under Recovery 2021-01-012021-12-31 C000530 MEADOWVIEW - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 34.5, 7.2, , 1.5,  2021-01-012021-12-31 C000530 Felman Prem/Discount ENEC-WV 2021-01-012021-12-31 C000530 Other State Tax, KY, 2019 , -2397 2021-12-31 C000530 Property Tax, LA, 2021 , 1115 2021-12-31 C000530 Winfield Hydro Project #1290 - Proportion of cost of administering the Federal Water Power Act 2021-01-012021-12-31 C000530 Income Tax, VA, 2021 ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 LOONEY CREEK - VA, Transmission, , 138, 69, 34.5, 90,  2021-01-012021-12-31 C000530 0473 CARETTA, JIM BRANCH, , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 EDGEMONT - VA, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 0011 KYGER CREEK, WV, TRI-STATE, WV, 3, 63, 0, 2303KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ALUM CREEK - WV, Distribution, , 46, 13.09, , 9.38,  2021-12-31 C000530 HALES BRANCH - VA, Transmission, , 138, 69, 12, 84,  2021-12-31 C000530 Public Authority-Large General Svc-TOD-Sec , 1691 , 179527 2021-01-012021-12-31 C000530 GARDEN CREEK - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 HANCOCK - VA, Transmission, , 34.5, 36.2, , 15,  2021-01-012021-12-31 C000530 0120 BEAVER CREEK, KY, CLINCH RIVER, VA, 3, 26, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0356 PEMBERTON TAP, WV, , 1, 0, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Distribution Expenses - Maintenance, AEPSC , 1513941.54 2021-01-012021-12-31 C000530 PJM - #AF2-291  , -147.37ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 BALD KNOB - WV, Distribution, , 46, 12, , 2.5,  2021-01-012021-12-31 C000530 HAYSI - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 ferc:ElectricUtilityMember APCo T Work (Supplemental) 2021-12-31 C000530 0135 AXTON, VA, DANVILLE #2, VA, 3, 16, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 LUKENS - VA, Distribution, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 BRADLEY - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Amortize through June 2026 2021-01-012021-12-31 C000530 HEWETT - WV, Distribution, , 46, 12, , 10.5,  2021-12-31 C000530 HALLS RIDGE - WV, Distribution, , 138, 34.5, , ,  2021-01-012021-12-31 C000530 PJM - #AD2-179  , -34.42 2021-01-012021-12-31 C000530 316 - Mountaineer, 22949000, P60Y, 0.0254 2021-01-012021-12-31 C000530 Other State Tax, VA, 2020 , 952200 2021-12-31 C000530 242 - Misc Current & Accrued Liab 2021-01-012021-12-31 C000530 PJM - #AG1-194  , 1038.16ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0225 AMOS, WV, SOUTH BUFFALO CIR B, WV, 3, 12, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PIPERS GAP - VA, Distribution, , 138, 36.2, , 30,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 12, , 5.25,  2021-01-012021-12-31 C000530 0225A LEON LOOP, WV, , 3, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 MIDDLE BURNING CREEK - WV, Distribution, , 34.5, 12, , 5,  2021-01-012021-12-31 C000530 ferc:OtherStateTaxMember 2020-12-31 C000530 Defd Carrying Charges - Reliability Capital - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-01-012021-12-31 C000530 (Increase) Decrease in other special deposits 2020-01-012020-12-31 C000530 NBV ARO's Retired Plants - Rate Order: VA SCC PUE-2014-0026 - Rate Order: WV PSC 14-1151-E-D 2021-12-31 C000530 0160 CLOVERDALE, VA, REUSENS, VA, 1, 1, 0, 636 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0216B BRADLEY, WV, TAMS MOUNTAIN, WV, 1, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO: 2020-2021 MW Upgrades 2021-12-31 C000530 AE1-108 , 54704.37ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:ElectricPlantHeldForFutureUseMember 2020-12-31 C000530 VA Sales/Use Tax Surcharge 2021-12-31 C000530 Income Tax, TN, 2017 , 2021-12-31 C000530 BANCROFT - WV, Transmission, , , 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 PJM AC1-122 & 123 , 2021-01-012021-12-31 C000530 0063 BROADFORD, VA, SALTVILLE NO.1A&1B, VA, 3, 4, 2, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CAMBRIA - VA, Distribution, , 69, 13.09, , 25,  2021-12-31 C000530 7% 2021-01-012021-12-31 C000530 0229 MERRIMAC TAP, VA, , 1, 7, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLIFFORD - VA, Transmission, , 138, 69, 46, 50,  2021-01-012021-12-31 C000530 361 - VA, 41443000, 0.0246 2021-01-012021-12-31 C000530 MARTINSVILLE - VA, Transmission, , 138, 70.5, 36.2, 108,  2021-12-31 C000530 MARSH FORK - WV, Distribution, , 46, 12, , 10.5,  2021-01-012021-12-31 C000530 CHERRY CREEK - WV, Distribution, , 138, 46, , 90,  2021-01-012021-12-31 C000530 Income Tax, MI, 2017 , 2021-12-31 C000530 ferc:FranchiseTaxMember 2021-12-31 C000530 GARDEN CREEK - VA, Transmission, , 138, 69.5, 13.09, 84,  2021-01-012021-12-31 C000530 LGS-TOD - Large General Service-T , 25728 2021-01-012021-12-31 C000530 SGS-TOD-Small General Service , 48906 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember AM CCR/ELG Compliance 2021-12-31 C000530 D/AP/Distribution Work 2021-01-012021-12-31 C000530 SKIN FORK - WV, Distribution, , 46, 12, , 8.4,  2021-01-012021-12-31 C000530 0090 SOUTH POINT, OH, TRI-STATE CIR A, WV, 3, 8, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WV EE/DR - Company Funded - Case No. PUE-2014-00039 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember MT HP TURBINE CP REFURBISH 2021-12-31 C000530 BENT MOUNTAIN - VA, Distribution, , 138, 13.09, , 8.4,  2021-01-012021-12-31 C000530 ferc:FranchiseTaxMember 2020-12-31 C000530 CHEMICAL - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Broadband Study 2021-01-012021-12-31 C000530 SEVENTH STREET - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Income Tax, WV, 2019 , 2021-12-31 C000530 0370 SOUTHRIDGE EXTENSION, , 1, 2, 2, 1590KCM ACSR/MA, 0, 0 2021-01-012021-12-31 C000530 MULLENS - WV, Transmission, , 138, 34.5, , 25,  2021-12-31 C000530 PJM INTERCONNECTION, RQ, VARIOUS 2021-01-012021-12-31 C000530 ELM STREET - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 Carbon Capture and Storage Project FEED Study Costs - Rate Order: WV PSC Case 13-0467-E-GI 2021-01-012021-12-31 C000530 Contr In Aid of Constr Advance 2021-12-31 C000530 MONETA - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 VINTON - VA, Distribution, , 138, 13.09, , 25,  2021-01-012021-12-31 C000530 AMHERST - VA, Distribution, , 69, 13.09, , 25,  2021-01-012021-12-31 C000530 334, 12780000, 0.0366 2021-01-012021-12-31 C000530 CLAYTOR HILLTOP - VA, Transmission, , , 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 MT ELG/CCR Compliance 2021-01-012021-12-31 C000530 Fleet and Vehicle Charges, AEPSC , 4103749 2021-01-012021-12-31 C000530 EAST RIVER MOUNTAIN - WV, Distribution, , 138, 34.5, , 9.38,  2021-01-012021-12-31 C000530 LATROBE - WV, Distribution, , 46, 7.2, , 4.5,  2021-01-012021-12-31 C000530 WELCH - WV, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 PAX BRANCH 138KV - WV, Transmission, , 138, 12, , 20,  2021-12-31 C000530 321, b, 93 2021-01-012021-12-31 C000530 LUKENS - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 Income Tax, MI, 2020 , 2021-12-31 C000530 MERRIMAC - VA, Transmission, , 138, 69, 12, 128,  2021-01-012021-12-31 C000530 0226 AMOS, WV, CHEMICAL #1 A, WV, 3, 1, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Materials and Supplies, KPCo , 251959.1 2021-01-012021-12-31 C000530 LPS-TOD-Large Power Ser TOD , 28276 2021-01-012021-12-31 C000530 Central Appalachian Coal Company 2021-01-012021-12-31 C000530 0ferc:AugustMember 2021-01-012021-12-31 C000530 Local Tax, WV, 2021 , 11076357 2021-12-31 C000530 ferc:AllocationOfPayrollChargedForClearingAccountsMember 2021-01-012021-12-31 C000530 0355 NAGEL, TN, WEST KINGSPORT, TN, 1, 0, 0, , 0, 0 2021-01-012021-12-31 C000530 BECCO - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ferc:ExciseTaxMember 2020-12-31 C000530 0461 George Street, South Lynchburg, 2, 0, 1, 1233.6KCM ACSR/TW, 0, 0 2021-01-012021-12-31 C000530 HALLS RIDGE - WV, Distribution, , 138, 34.5, , ,  2021-12-31 C000530 HOPKINS FORK - WV, Distribution, , 46, 7.2, , 2.49,  2021-12-31 C000530 Franchise Tax, TN, 2019 , 2020-12-31 C000530 PJM - #AE2-292  , -18.44 2021-01-012021-12-31 C000530 Income Tax, VA, 2021 , 2021-12-31 C000530 TURNER - WV, Transmission, , 138, 69, 46, 84,  2021-01-012021-12-31 C000530 0053 BAILEYSVILLE, WV, HALES BRANCH, VA, 1, 21, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 GILBERT - WV, Distribution, , 46, 12, , 20,  2021-12-31 C000530 320, b, 5 2021-01-012021-12-31 C000530 CHEMICAL - WV, Transmission, , 138, 69, 46, 84,  2021-01-012021-12-31 C000530 WITT - VA, Distribution, , 69, 4.36, , 12.5,  2021-01-012021-12-31 C000530 WYOMING - WV, Transmission, , 765, 138, 12, 250,  2021-01-012021-12-31 C000530 ferc:FederalTaxMember 2020-12-31 C000530 PJM - #AG1-314  , 384.85ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 Franchise Tax, NC, 2018 , 2021-12-31 C000530 Franchise Tax, TN, 2021 , 2020-12-31 C000530 Income Tax, MI, 2021 , 2020-12-31 C000530 VCEA Virginia RPS Under Recovery 2021-12-31 C000530 0518 TOWN CREEK, SOUTH BLUEFIELD, 3, 10, 1, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0123 BEAVER CREEK, KY, FREMONT, VA, 3, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 GLADE - VA, Distribution, , 69, 34.5, , 30,  2021-12-31 C000530 PIPERS GAP - VA, Distribution, , 138, 34, , 30,  2021-12-31 C000530 HILL - VA, Transmission, , 138, 69, 34.5, 40,  2021-12-31 C000530 TEAYS - WV, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 RIDGEWAY - VA, Transmission, , 138, 69, 4, 40,  2021-01-012021-12-31 C000530 BALD KNOB - WV, Distribution, , 46, 12, , 2.5,  2021-12-31 C000530 PJM - #AE2-047  , -57.48 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO Distr Pre Eng Parent 2021-01-012021-12-31 C000530 ACCOVILLE - WV, Distribution, , 69, 46, 1.6, 7.5,  2021-12-31 C000530 Southern Appalachian Coal Company 2021-01-012021-12-31 C000530 BOXWOOD - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 0333 BROADFORD, VA, RICHLANDS, VA, 2, 14, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0417 BAILEYSVILLE, WV, HALES BRANCH, VA, 3, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Civil & Political Activities and Other Svcs, AEPSC , 1319131.66 2021-01-012021-12-31 C000530 312 - Clinch River, 214933000, P67Y, 0.0543 2021-01-012021-12-31 C000530 BROWNSVILLE (AP) - WV, Distribution, , 69, 12, , 6.25,  2021-01-012021-12-31 C000530 315 - Amos U1&2, 57653000, P61Y, 0.0391 2021-01-012021-12-31 C000530 HUNTINGTON COURT - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember NIH RELICENSE NIAGARA HYDRO 2021-01-012021-12-31 C000530 RIVERBEND - VA, Distribution, , 69, 12, , 9.38,  2021-01-012021-12-31 C000530 - Expense, Premium (P), Discount (D) 2021-01-012021-12-31 C000530 TURNER - WV, Transmission, , 138, 70.5, 46, 54,  2021-12-31 C000530 John Vaughan Truck Garage 2021-01-012021-12-31 C000530 PJM - #AF2-106  , -375.09ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 Facility Rent, WVTCo , 2610035 2021-01-012021-12-31 C000530 HUNTINGTON COURT - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:ElectricUtilityMember Forestry - APCo-T 2021-01-012021-12-31 C000530 OHIO POWER COMPANY (AUCTION), OS, NOTE 1 2021-01-012021-12-31 C000530 HUFF CREEK - WV, Transmission, , 138, 69, 46, 130,  2021-01-012021-12-31 C000530 0114 HANCOCK, VA, ROANOKE, VA, 3, 5, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo DISTR Work 2021-01-012021-12-31 C000530 Def Equity Income-Securitization 2021-12-31 C000530 OAK LEVEL - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 JIM BRANCH - WV, Transmission, , 69, 12, , 10,  2021-12-31 C000530 POINT PLEASANT - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ELM STREET - VA, Distribution, , 34.5, 12, , 20,  2021-01-012021-12-31 C000530 0322 JOSHUA FALLS, VA, REUSENS A&B, VA, 1, 0, 2, 1590KCM ACSR, , 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AE2-140  , -368.74 2021-01-012021-12-31 C000530 GRAND RIDGE WIND FARM 3, OS, 2021-01-012021-12-31 C000530 MUD FORK - WV, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 OL-Outdoor Lighting , 3025 , 367950 2021-01-012021-12-31 C000530 DAMERON - WV, Transmission, , 138, 69, 46, 129,  2021-01-012021-12-31 C000530 BLUE PENNANT - WV, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 RONDA - WV, Distribution, , 46, 12, , 3.75,  2021-12-31 C000530 Lines Sold 2021-12-31 C000530 HILLMAN HIGHWAY - VA, Distribution, , 69, 13.09, , 25,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA (C), Transmission, , 138, 70.5, 13.09, 78,  2021-12-31 C000530 Dresden Operating Costs - VA - Rate Order: VA SCC PUE-2011-00036 2020-12-31 C000530 Other License And Fees Tax, WV, 2020 , 2021-12-31 C000530 315 - Clinch River, 10961000, P67Y, -0.0131 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/Charleston to Roanoke Tel 2021-12-31 C000530 SFAS 109 Deferred State Income Tax 2020-12-31 C000530 CENTERVILLE - VA, Transmission, , 138, 69, 34.5, 84,  2021-12-31 C000530 PJM - #AD1-017  , 23.82 2021-01-012021-12-31 C000530 AMHERST - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 370 - WV, 41528000, 0.1243 2021-01-012021-12-31 C000530 PAX BRANCH 138KV - WV, Transmission, , 138, 46, , 216,  2021-01-012021-12-31 C000530 0354 NAGEL, TN, WEST KINGSPORT, TN, 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0097 CAPITOL HILL, WV, CHEMICAL, WV, 3, 0, 1, 1272KCM ACSS, , 2021-01-012021-12-31 C000530 AMOS 765KV - WV, Transmission, , 765, 345, 34.5, 1500,  2021-01-012021-12-31 C000530 EDWIGHT - WV, Distribution, , 46, 7.2, , 2.49,  2021-01-012021-12-31 C000530 Sporn Plant 2021-12-31 C000530 Local Tax, , 2019 , 2020-12-31 C000530 Def Lease Assets - Non Taxable 2021-01-012021-12-31 C000530 DARRAH - WV, Transmission, , 138, 69, 34.5, 90,  2021-12-31 C000530 CLIFFORD - VA, Transmission, , 138, 69, 46, 50,  2021-12-31 C000530 EAST DANVILLE - VA, Transmission, , 69, 12, , 8.4,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 13.09, , 20,  2021-12-31 C000530 DEARINGTON - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Franchise Tax, NC, 2017 , 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other State Tax, WV, 2020 , 1565569 2021-01-012021-12-31 C000530 RS-EV RESIDENTIAL SERVICE PLUG IN ELECTRIC VEHICLE CHARGING , 142 2021-01-012021-12-31 C000530 0156A CLIFFORD, VA, REUSENS, VA, 3, 23, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 AF2-382 , 13264.59ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0, CLAYTOR 2021-12-31 C000530 Ceredo 2021-12-31 C000530 Other Taxes, WV, 2021 , 2021-12-31 C000530 VETERANS HOSPITAL - VA, Distribution, , 34.5, 4, , 10,  2021-01-012021-12-31 C000530 ARROWHEAD - VA, Distribution, , 69, 13.09, , 12,  2021-12-31 C000530 MGS-Medium General Service , 136850 2021-01-012021-12-31 C000530 SLAB FORK - WV, Distribution, , 46, 7.2, , 0.99,  2021-01-012021-12-31 C000530 BRADLEY - WV, Transmission, , 138, 69, 46, 130,  2021-01-012021-12-31 C000530 0, SMITH MOUNTAIN 2021-01-012021-12-31 C000530 AE1-250 , 169088.76 2021-01-012021-12-31 C000530 0225 SOUTH BUFFALO, WV, SPORN CIR A, WV, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 MORGANS CUT - VA, Transmission, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Income Tax, IL, 2020 , 2021-01-012021-12-31 C000530 SGS-PA -Small Gen Ser - PA , 952 , 120991 2021-01-012021-12-31 C000530 SPRIGG - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 SHARPLES - WV, Distribution, , 46, 12, , 4.69,  2021-01-012021-12-31 C000530 SHAWSVILLE - VA, Distribution, , 138, 13.09, , 10.5,  2021-12-31 C000530 Capital Environmental Equity Costs - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-12-31 C000530 Carrying Chgs-VA Broadband Pilot - VA SCC Case No. PUR-2019-00145 2020-12-31 C000530 ABINGDON - VA, Transmission, , 138, 70.5, 13.09, 90,  2021-12-31 C000530 PJM - #AE1-176  , -22.03ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 HYDRO PUMPED, , 2021-01-012021-12-31 C000530 BOWYER - WV, Distribution, , 46, 7.2, , 3,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 34, , 20,  2021-01-012021-12-31 C000530 KENOVA - WV, Transmission, , 34.5, 4, , 3.75,  2021-12-31 C000530 COAL MOUNTAIN - WV, Distribution, , 46, 7.2, , 1.66,  2021-12-31 C000530 , 27 Item(s) Under $50,000 2021-01-012021-12-31 C000530 APCo DISTR Work 2021-01-012021-12-31 C000530 0088 TRI-STATE, WV, WEST HUNTINGTON, WV, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CAPITOL HILL 138KV - WV, Transmission, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 GLADE - VA, Distribution, , 69, 12, , 10.5,  2021-12-31 C000530 NBV ARO's Retired Plants - Rate Order: VA SCC PUE-2014-0026 - Rate Order: WV PSC 14-1151-E-D 2021-01-012021-12-31 C000530 364 - VA, 431175000, 0.0365 2021-01-012021-12-31 C000530 0090 SOUTH POINT, OH, TRI-STATE CIR B, WV, 3, 0, 1, 1351KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AE2-280  , -63.09 2021-01-012021-12-31 C000530 IP-Industrial Power Service , 6995 2021-01-012021-12-31 C000530 Deferred Fuel Costs 2021-01-012021-12-31 C000530 BROCKWAY GLASS - VA, Distribution, , 69, 4, , 9.38,  2021-12-31 C000530 Other State Tax, OH, 2020 , 320 2021-12-31 C000530 0517 Town Creek, Progress Park, 3, 3, 1, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 REUSENS - VA, Transmission, , 138, 69, 13.09, 130,  2021-01-012021-12-31 C000530 FLATWOOD - WV, Distribution, , 138, 12.47, , 22.4,  2021-01-012021-12-31 C000530 Property Tax, OH, 2019 , 1916228 2020-12-31 C000530 FIELDCREST MILLS - VA, Distribution, , 69, 4, , 20,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember AG1-468 , 1900.52 2021-01-012021-12-31 C000530 398, 8105000, 0.0273 2021-01-012021-12-31 C000530 Income Tax, KY, 2021 ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 PRICES FORK - VA, Distribution, , 69, 13.09, , 25,  2021-12-31 C000530 MILTON - WV, Transmission, , 138, 69, 34.5, 90,  2021-01-012021-12-31 C000530 346 Dresden Plant, 30900000, 0.0374 2021-01-012021-12-31 C000530 PEMBERTON - WV, Transmission, , 138, 69, 46, 90,  2021-12-31 C000530 KILLARNEY - WV, Distribution, , 46, 7.2, , 1.16,  2021-12-31 C000530 MGS-PA-Med Gen Ser - PA , 543 , 48873 2021-01-012021-12-31 C000530 3,000 shares common stock 2021-01-012021-12-31 C000530 ferc:NitrogenOxideMemberferc:ThreeYearsMember 2021-01-012021-12-31 C000530 KENOVA - WV, Transmission, , 138, 69, 46, 150,  2021-01-012021-12-31 C000530 DISSTON - VA, Distribution, , 69, 4, , 3.13,  2021-12-31 C000530 Virginia Clean Economy Act Filing 2021-12-31 C000530 CLIFFORD - VA, Transmission, , 138, 46, , 20,  2021-12-31 C000530 NORTH BECKLEY - WV, Distribution, , 138, 13.09, , 25,  2021-01-012021-12-31 C000530 Other State Tax, WV, 2020 , 1565569 2021-12-31 C000530 Property Tax, OH, 2020 , 9 2020-12-31 C000530 APCo Distribution Work 2021-01-012021-12-31 C000530 Capital Contributions Central Appalachian Coal Company 2021-01-012021-12-31 C000530 336 - Marmet Hydro, 1000, 0.0116 2021-01-012021-12-31 C000530 AG1-219 , 1879.94ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 CATAWBA - VA, Transmission, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 BELCHER MOUNTAIN - WV, Distribution, , 88, 14, , 4.5,  2021-01-012021-12-31 C000530 CLINCHFIELD - VA, Transmission, , 138, 70.5, 36.2, 90,  2021-01-012021-12-31 C000530 MIKES RUN - WV, Distribution, , 46, 12, , 3.75,  2021-01-012021-12-31 C000530 0256 LEBANON 138KV TAP VA, , 1, 0, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 138, 70.5, 36.2, 200,  2021-12-31 C000530 0016A CARSWELL TAP, WV, , 3, 1, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0567 Glenmary Extension, , 3, 0, 2, 795KCM ACSR, , 2021-01-012021-12-31 C000530 0524 Joshua Falls 765/138kV Bus Tie No. 1, , 1, 0, 1, 1590KCM ACSR, , 2021-01-012021-12-31 C000530 ferc:NitrogenOxideMemberferc:NextTwelveMonthsMember 2021-01-012021-12-31 C000530 BOONE - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 Property Tax, OH, 2019 , 1916228 2021-12-31 C000530 0228 AMOS, WV, HOPKINS, WV, 3, 28, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 GRUNDY - VA, Transmission, , 69, 34.5, , 25,  2021-01-012021-12-31 C000530 SOUTH BUFFALO - WV, Distribution, , 138, 36.2, , 30,  2021-01-012021-12-31 C000530 Property Tax, VA, 2020 , 803447 2021-01-012021-12-31 C000530 Southern Appalachian Coal Company 2021-12-31 C000530 DUNBAR - WV, Distribution, , 46, 13.09, , 20,  2021-12-31 C000530 LPS-TOD-Large Power Ser TOD , 1031038 2021-01-012021-12-31 C000530 STARKEY - VA, Distribution, , 138, 13.09, , 40,  2021-12-31 C000530 MGS-Medium General Service , 239422 2021-01-012021-12-31 C000530 Income Tax, MI, 2019 , 2020-12-31 C000530 MEADOWVIEW - VA, Distribution, , 138, 69, 34.5, 56,  2021-01-012021-12-31 C000530 Central Machine Shop, OPCo , 367854 2021-01-012021-12-31 C000530 COFFEE - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 0435 DUTY, VA, 138KV EXTENSION, , 0, 1, , 0, 0 2021-01-012021-12-31 C000530 CEDAR GROVE (AP) - WV, Distribution, , 46, 12, , 5,  2021-12-31 C000530 Barging, I&M , 40129351 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 12, , 7.5,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Property Tax, WV, 2020 , 26656291 2021-01-012021-12-31 C000530 TULTEX - VA, Distribution, , 34.5, 7.5, , 2.5,  2021-12-31 C000530 MASON CREEK - VA, Distribution, , 69, 12, , 25,  2021-12-31 C000530 Franchise Tax, TN, 2018 , 2021-01-012021-12-31 C000530 LEIVASY - WV, Distribution, , 69, 12, , 8.4,  2021-12-31 C000530 SPRIGG - WV, Transmission, , 138, 34.5, , 25,  2021-12-31 C000530 MT CI SCR CATALYST 2ND LAYERferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 0163 MOSELEY, VA, ROANOKE, VA, 3, 1, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SWITCHBACK - WV, Transmission, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 LOCKHART - VA, Distribution, , 138, 13.04, , 20,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Ed-Ci-Apco-D Ast Imp 2021-12-31 C000530 CLINCHFIELD - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0ferc:JulyMember 2021-01-012021-12-31 C000530 SUNSCAPE - VA, Distribution, , 138, 12, , 20,  2021-01-012021-12-31 C000530 AMONATE LIGHTS - WV, Distribution, , 34.5, 7.2, , 0.75,  2021-01-012021-12-31 C000530 ORCHARD - VA, Distribution, , 34.5, 12, , 6.25,  2021-12-31 C000530 0539 Tri State 345kV, 138kV Bus Tie No. 1, 3, 2021-01-012021-12-31 C000530 0058 GLEN LYN, VA, WYTHE, VA, , 1, 0, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Franchise Tax, TN, 2017 , 2020-12-31 C000530 0ferc:JanuaryMember 2021-01-012021-12-31 C000530 2,000 shares common stock 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/Danville - Martinsville T 2021-01-012021-12-31 C000530 Equity Carrying Chgs-VA Broadband Pilot - VA SCC Case No. PUR-2019-00145 2021-01-012021-12-31 C000530 ABINGDON - VA, Transmission, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 GRUNDY - VA, Transmission, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 MOUNT UNION - VA, Transmission, , 69, 12, , 20,  2021-12-31 C000530 AF1-049 , 8951.31 2021-01-012021-12-31 C000530 BROWNSVILLE (AP) - WV, Distribution, , 69, 12, , 6.25,  2021-12-31 C000530 334 - Winfield Hydro, 270000, 0.0318 2021-01-012021-12-31 C000530 Central Coal Company 2021-12-31 C000530 SKIN FORK - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 0, BYLLESBY 2021-12-31 C000530 ferc:ElectricUtilityMember CIAC 2020-12-31 C000530 0142 EAST DANVILLE NO. 2,VA, ROXBORO, NC, 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Property Taxes West Virginia 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo-D Service Restoration Blk 2021-01-012021-12-31 C000530 NORTH POINTE - WV, Distribution, , 138, 34.5, , 20,  2021-01-012021-12-31 C000530 HEWETT - WV, Distribution, , 46, 12, , 10.5,  2021-01-012021-12-31 C000530 FARADAY 138KV - WV, Distribution, , 34.5, 0, 0, 0, AIR CORE REACTOR 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo AMI Project VA 2021-12-31 C000530 WV Broadband Over Recovery 2021-12-31 C000530 MONTGOMERY - WV, Distribution, , 46, 12, , 22.4,  2021-12-31 C000530 ferc:ElectricUtilityMember Income Tax, WV, 2021 , 2021-01-012021-12-31 C000530 PJM - #AF1-049  , -150.63 2021-01-012021-12-31 C000530 AG2-311 , 872.69 2021-01-012021-12-31 C000530 Income Tax, TN, 2021 , 147400 2021-01-012021-12-31 C000530 MERRIMAC - VA, Transmission, , 138, 69, 12, 128,  2021-12-31 C000530 PAX BRANCH 138KV - WV, Transmission, , 138, 12, , 20,  2021-01-012021-12-31 C000530 SOUTH LYNCHBURG - VA, Transmission, , 138, 70.5, 36.2, 78,  2021-12-31 C000530 Property Taxes Ohio 2021-01-012021-12-31 C000530 Proceeds on Capital Leaseback 2020-01-012020-12-31 C000530 Investment in Premium on Common Stock 2021-01-012021-12-31 C000530 0527 COCO Extension, , 1, 0, 2, 1033.5 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 FERC Formula Rates Under Recovery 2021-12-31 C000530 Property Tax, VA, 2019 , 943 2020-12-31 C000530 0483 HERNSHAW, 138KV EXTENSION, 3, 2, 2, 1590 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WHEATLAND - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 185 - ODD Temporary Facilitiesferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C000530 Real Estate & Workplace Svcs, AEPSC , 3797285.49 2021-01-012021-12-31 C000530 JUBAL EARLY - VA, Transmission, , 138, 70.5, 36.2, 108,  2021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, , 13.8, 250,  2021-12-31 C000530 Carrying Chgs-COVID-19 Costs - VA SCC Case No. PUR-2020-00074 2021-01-012021-12-31 C000530 CAMPBELL AVENUE - VA, Distribution, , 69, 12, , 44.8,  2021-12-31 C000530 ferc:AfterThreeYearsMemberferc:SulfurDioxideMember 2021-12-31 C000530 WYOMING - WV, Transmission, , 765, 138, 13.8, 1250,  2021-01-012021-12-31 C000530 HOPKINS - WV, Transmission, , 138, 69, 46, 56,  2021-12-31 C000530 FOUR POLE CREEK - WV, Distribution, , 34.5, 4.16, , 4.5,  2021-12-31 C000530 GALLAGHER - WV, Distribution, , 46, 12, , 4.69,  2021-12-31 C000530 0344 CULLODEN, WV, GAVIN, OH, 3, 42, 1, 1351KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0271 BLUEFIELD, WV, TAZEWELL, VA, 1, 1, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0417 BAILEYSVILLE, WV, HALES BRANCH, VA, 1, 6, 0, , 0, 0 2021-01-012021-12-31 C000530 WEST BASSETT - VA, Transmission, , 34.5, 34.5, , 25,  2021-12-31 C000530 FRANKLIN STREET - VA, Distribution, , 34.5, 12, , 6.25,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 13.09, , 7.5,  2021-12-31 C000530 Ed-Ci-Apco-D Cust Serv 2021-01-012021-12-31 C000530 Otherferc:NitrogenOxideMember 2021-01-012021-12-31 C000530 RIPLEY - WV, Distribution, , 69, 34.5, , 25,  2021-12-31 C000530 VA Distribution Substation Depreciation Deferral 2021-12-31 C000530 JUBAL EARLY - VA, Transmission, , 138, 70.5, 36.2, 108,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AF2-382  , 2340.48 2021-01-012021-12-31 C000530 0032 BRADLEY CIR A, WV, GLEN LYN-HINTON, VA, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Franchise Tax, TN, 2021 , 2021-01-012021-12-31 C000530 VETERANS HOSPITAL - VA, Distribution, , 34.5, 4, , 10,  2021-12-31 C000530 ferc:NitrogenOxideMember Purchases/Transfers: 2021-01-012021-12-31 C000530 PJM Trans Enhancement Rev - Affil Various Various FNO 2021-01-012021-12-31 C000530 PROGRESS PARK - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 0183 AMOS, WV, CULLODEN, WV, 3, 954KCM ACSR 2021-01-012021-12-31 C000530 Property Tax, WV, 2019 , 26137350 2021-01-012021-12-31 C000530 0093 BIG SANDY, WEST HUNTINGTON, WV, 2, 0, 2, 1780KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Customer Support, AEPSC , 2262305.11 2021-01-012021-12-31 C000530 0241A HUFFMAN, VA, JACKSONS FERRY, VA, 3, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Amortization of Regulatory Debits and Credits 2020-01-012020-12-31 C000530 Def Lease Assets - Non Taxable 2020-12-31 C000530 312 - Mountaineer SCR, 18740000, P8Y, 0.1085 2021-01-012021-12-31 C000530 WURNO - VA (B), Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 0135 AXTON, VA, DANVILLE #2, VA, 3, 1, 1, 795KCM SSAC, 0, 0 2021-01-012021-12-31 C000530 WYOMING - WV, Transmission, , 765, 138, 12, 250,  2021-12-31 C000530 FLOYD - VA, Transmission, , 138, 12, , 9.38,  2021-12-31 C000530 CEREDO - WV, Distribution, , 34.5, 4, , 6.25,  2021-01-012021-12-31 C000530 Consent Decree Surrendersferc:SulfurDioxideMember 2021-01-012021-12-31 C000530 LPS-Large Power Service , 3261288 2021-01-012021-12-31 C000530 Associated Business Development 2021-01-012021-12-31 C000530 MCGRAWS - WV, Distribution, , 46, 13.09, , 12.5,  2021-12-31 C000530 LONESOME PINE - VA, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 GS - General Sales , 4 2021-01-012021-12-31 C000530 STATE OF TENNESSEE, STATE OF TENNESSEE, , 2021-01-012021-12-31 C000530 CRAB ORCHARD - WV, Distribution, , 46, 12, , 3.75,  2021-12-31 C000530 314 - Clinch River, 40581000, P67Y, -0.0237 2021-01-012021-12-31 C000530 NEW CASTLE - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ROANOKE (AP) - VA, Transmission, , 138, 13.09, , 20,  2021-12-31 C000530 VINTON - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 0216 MULLENS, WV, TAMS MOUNTAIN, WV, 1, 0, 0, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, TN, 2016 , 2021-12-31 C000530 0115 CELANESE, VA, MATT FUNK, VA, 3, 34, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BANCROFT - WV, Transmission, , , 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:ElectricUtilityMember Interest Expense Capitalized for Tax 2021-01-012021-12-31 C000530 HARDY - WV, Distribution, , 46, 7.2, , 4.5,  2021-12-31 C000530 Aquired Assets 2021-01-012021-12-31 C000530 Equity Costs - Capital Reliability - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2020-12-31 C000530 BOONSBORO - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 Property Tax, WY, 2020 , 2312 2020-12-31 C000530 0368 CLAY POOL HILL LOOP,VA, , 1, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Marmet and London Hydro Project #1175 - Proportion of cost of administering the Federal Water Power Act 2021-01-012021-12-31 C000530 Undistributed earnings/losses and dividends - Cedar Coal Company 2020-12-31 C000530 Materials and Supplies, I&M , 561541.04 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Income Tax, MI, 2021 , 2021-01-012021-12-31 C000530 0098 CAPITOL HILL, WV, KANAWHA, WV, 3, 3, 1, 556KCM ACSS, 0, 0 2021-01-012021-12-31 C000530 PJM - #AE2-185  , -59.83ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 Virginia Transmission RAC Filing 2021-12-31 C000530 Meter Correction 2021-01-012021-12-31 C000530 335 - Leesville Hydro, 3123000, 0.0334 2021-01-012021-12-31 C000530 STUART - VA, Distribution, , 69, 34.5, , 30,  2021-01-012021-12-31 C000530 ABERT - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 KNOTTY POPLAR - VA, Distribution, , 69, 12, , 6.25,  2021-12-31 C000530 ferc:ElectricUtilityMember APCo T Work 2021-12-31 C000530 186 - Misc Deferred Debitsferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C000530 0161 CLOVERDALE, VA, ROANOKE, VA, 3, 1, 0, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0378 CURRY LOOP, WV, , 3, 2, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Excise Tax, , 2021 , 16433 2020-12-31 C000530 Virginia Blue Ridge Petition Filing 2021-12-31 C000530 WEST HUNTINGTON - WV, Transmission, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 SOUTH LYNCHBURG - VA, Transmission, , 138, 69, 34.5, 50,  2021-01-012021-12-31 C000530 JOSHUA FALLS - VA, Transmission, , 765, 138, 13.8, 750,  2021-12-31 C000530 CLH 3 Tailrace Disolved Oxygen 2021-01-012021-12-31 C000530 OLD DOMINION ELECTRIC, RQ, NOTE 1 2021-01-012021-12-31 C000530 TOWER 117 - WV, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 CHESTERFIELD AVENUE - WV, Transmission, , 138, 13.09, , 40,  2021-12-31 C000530 0115 CELANESE, VA, MATT FUNK, VA, 3, 0, 2, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:NitrogenOxideMemberferc:CurrentYearMember 2020-12-31 C000530 FLATWOOD - WV, Distribution, , 138, 12.47, , 22.4,  2021-12-31 C000530 PETERS MOUNTAIN - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 EAST HUNTINGTON - WV, Transmission, , 34.5, 12, , 9.38,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Unit 2 Turbine Rotors A & B 2021-01-012021-12-31 C000530 Other Taxes, WV, 2020 , 731496 2021-01-012021-12-31 C000530 APCo D (Floyd-Stuart Area) 2021-01-012021-12-31 C000530 AF2-382 , 13264.59 2021-01-012021-12-31 C000530 AXTON - VA, Transmission, , 138, 0, 0, 0, AIR CORE REACTOR 2021-01-012021-12-31 C000530 PJM - #AE2-185  , -59.83 2021-01-012021-12-31 C000530 352, 169425000, 0.0186 2021-01-012021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, , , 250,  2021-01-012021-12-31 C000530 WURNO - VA (B), Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 Niagara - Project #2466 2021-12-31 C000530 FALLING BRANCH - VA, Distribution, , 138, 13.09, , 9.38,  2021-01-012021-12-31 C000530 0416 CLOVERDALE, VA, HUNTINGTON COURT, VA, 3, 6, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLIFFORD - VA, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Greenhat Default Contingency 2020-12-31 C000530 HANS MEADOW - VA, Distribution, , 69, 13.09, , 25,  2021-01-012021-12-31 C000530 SGS-Small General Service , 833761 2021-01-012021-12-31 C000530 BUCKHORN - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember CIS-Common Deployment-APC D 2021-12-31 C000530 HAMPTON - WV, Distribution, , 46, 12, , 3.75,  2021-12-31 C000530 Income Tax, IL, 2019 , 2020-12-31 C000530 ferc:LandAndRightsMember Sheridan 69KV Substation, Lincoln County, WV 4.947 acres (2041) 2021-01-012021-12-31 C000530 Unemployment Tax, KY,  , 317 2020-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 345, 138, 34.5, 675,  2021-12-31 C000530 ferc:ElectricUtilityMember FICA 2021 , Federal Insurance Tax, ,  , 15810857 2021-01-012021-12-31 C000530 MOUNT VIEW - VA, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other 2021-12-31 C000530 ferc:IncomeTaxMember 2021-01-012021-12-31 C000530 WV EE/DR - Company Funded - Case No. PUE-2014-00039 2020-12-31 C000530 BANCROFT - WV, Transmission, , 138, 69, 12, 67.2,  2021-01-012021-12-31 C000530 COLLINSVILLE (AP) - VA, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 331, 16356000, 0.0214 2021-01-012021-12-31 C000530 NIH RELICENSE NIAGARA HYDRO 2021-01-012021-12-31 C000530 186 - Misc Deferred Debits 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember State DITC 2021-01-012021-12-31 C000530 0237 AMOS, WV, DARRAH, WV, 3, 35, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 STUART - VA, Distribution, , 69, 34.5, , 30,  2021-12-31 C000530 0482 CLARK BRANCH, WV, 138KV EXTENSION, , 0, 1, , 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other 2020-12-31 C000530 AMOS 765KV - WV, Transmission, , 765, 138, 13.8, 750,  2021-12-31 C000530 EAST DANVILLE - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 Other License And Fees Tax, WV, 2019 , 2021-12-31 C000530 BLAINE - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 B(4) Research Support to Others, 3 Item(s) under $50,000 2021-01-012021-12-31 C000530 332 - Byllesby Hydro, 7441000, 0.129 2021-01-012021-12-31 C000530 SOUTH HILLS - WV, Distribution, , 46, 13.09, , 25,  2021-12-31 C000530 LAKIN - WV, Transmission, , 138, 13.09, , 20,  2021-12-31 C000530 0258 OPOSSUM CREEK, VA, PEAKSVIEW, VA, 1, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Franchise Tax, TN, 2020 , 2020-12-31 C000530 0517 Town Creek, Progress Park, 1, 3, 1, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 RED HILL - VA, Distribution, , 138, 13.09, , 8.4,  2021-01-012021-12-31 C000530 GLEN LYN - VA, Transmission, , 138, 13.2, , 18.75,  2021-12-31 C000530 0061 ATKINS, VA, BROADFORD CIR A, VA, 3, 20, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HANS MEADOW - VA, Distribution, , 69, 13.09, , 25,  2021-12-31 C000530 WEST BASSETT - VA, Transmission, , 138, 69, 34.5, 128,  2021-12-31 C000530 VA Distribution Substation Carrying Charge Deferral 2021-01-012021-12-31 C000530 0518 TOWN CREEK, SOUTH BLUEFIELD, 2, 1, 1, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0055 GLEN LYN, VA, WYTHE, VA, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BASSETT WALKER - VA, Distribution, , 34.5, 7.5, , 3.75,  2021-12-31 C000530 SHARPLES - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Income Tax, IL, 2021 , 2021-01-012021-12-31 C000530 Undistributed earnings/losses and dividends - Central Appalachian Coal 2020-12-31 C000530 334 - Marmet Hydro, 2191000, 0.0221 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AG1-091  , -726.11 2021-01-012021-12-31 C000530 0112 MATT FUNK, VA, ROANOKE, VA, 3, 13, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SOUTH BLUEFIELD - WV, Transmission, , 138, 13.09, , 30,  2021-12-31 C000530 OLD DOMINION ELECTRIC, OS, 2021-01-012021-12-31 C000530 BARNETT - WV, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 WYTHE - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 Urea, KPCo , 964517.46 2021-01-012021-12-31 C000530 T/AP/CrningGls-Rdgewy69kv:Relo 2021-01-012021-12-31 C000530 POUND - VA, Distribution, , 69, 34.5, , 25,  2021-01-012021-12-31 C000530 DAMERON - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 OPOSSUM CREEK - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 AG1-311 , 1214.46 2021-01-012021-12-31 C000530 312 - Amos U1&2 SCR, 20163000, P61Y, 0.0726 2021-01-012021-12-31 C000530 Proceeds on Capital Leaseback 2021-01-012021-12-31 C000530 CARBONDALE - WV, Transmission, , 138, 69, 46, 128.8,  2021-12-31 C000530 SOUTH PRINCETON - WV, Distribution, , 138, 34.5, , 55,  2021-12-31 C000530 VA E-RAC Under Recovery 2021-12-31 C000530 Mountaineer Oil 2021-01-012021-12-31 C000530 Smith Mountain Combination Project #2210 - Proportion of cost of administering the Federal Water Power Act 2021-12-31 C000530 314 - Amos U1&2, 126216000, P61Y, 0.0496 2021-01-012021-12-31 C000530 GLENWOOD (AP) - VA, Distribution, , 12, 0.24, , 0.17,  2021-01-012021-12-31 C000530 HURRICANE - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 8161 CVEC, SCOTTSVILLE, 3, 1, 1, , 0, 0 2021-01-012021-12-31 C000530 ACCOVILLE - WV, Distribution, , 69, 46, 1.6, 7.5,  2021-01-012021-12-31 C000530 331 - Leesville Hydro, 3839000, P76Y, 0.0277 2021-01-012021-12-31 C000530 Lines Under 138KV, , , 1568, , , , 2021-01-012021-12-31 C000530 HILLSVILLE - VA, Distribution, , 34.5, 12, , 6.75,  2021-01-012021-12-31 C000530 GALAX - VA (A), Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 FLOYD - VA, Transmission, , 138, 69, 34.5, 56,  2021-12-31 C000530 WOLF GLADE - VA, Transmission, , 138, 70.5, 13.09, 78,  2021-01-012021-12-31 C000530 0045 LOGAN, WV, SPRIGG #1 & #2, WV, 3, 18, 2, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0113 CLAYTOR, VA, HANCOCK, VA, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ABERT - VA, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 0292 VINTON LOOP, VA, , 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0138 COLLINSVILLE, TAP LINE, , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 BORDERLAND - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO-D 2021-12-31 C000530 BENS CREEK - WV, Distribution, , 46, 13.2, , 2.5,  2021-12-31 C000530 Capital Contributions Central Coal Company 2021-01-012021-12-31 C000530 OCEANA - WV, Distribution, , 46, 12, , 16.75,  2021-12-31 C000530 VA Distribution Substation Depreciation Deferral 2021-01-012021-12-31 C000530 0230 AMOS, WV, TURNER #2, WV, 3, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0094 BIG SANDY, KY, DEWEY, KY, 3, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0337 BLUEFIELD, WV, SOUTH PRINCETON, WV, 2, 8, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0120 BEAVER CREEK, KY, CLINCH RIVER, VA, 1, 0, 0, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 AMOS 345KV - WV, Transmission, , 345, 138, 34.5, 1350,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA (H), Transmission, , 138, 70.5, 36.2, 78,  2021-01-012021-12-31 C000530 Sales And Use Tax, TN, 2020 , 6375 2021-01-012021-12-31 C000530 Other Taxes, WV, 2020 , 731496 2020-12-31 C000530 ferc:ElectricUtilityMember Property Tax, TN, 2020 , 1392679 2021-01-012021-12-31 C000530 HARDY - WV, Distribution, , 46, 7.2, , 4.5,  2021-01-012021-12-31 C000530 0522 SOUTH ABINGDON EXT, , 1, 4, 2, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CAPITOL HILL 138KV - WV, Transmission, , 138, 46, , 45,  2021-01-012021-12-31 C000530 WALNUT AVENUE - VA, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 ELK GARDEN - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 APCO: 2020 - 2022 RBB Graysonferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 CLENDENIN - WV, Transmission, , 138, 46, , 125,  2021-01-012021-12-31 C000530 0568 GRANGSTON LOOP, , 3, 0, 2, 556.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0330 JIM BRANCH, WV, WYOMING, WV, 1, 16, 0, , 0, 0 2021-01-012021-12-31 C000530 PJM - #AG1-022  , 1733.19ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 BLAINE - VA, Distribution, , 138, 13.09, , 8.4,  2021-12-31 C000530 BECCO - WV, Distribution, , 46, 12, , 9.38,  2021-12-31 C000530 Income Tax, WV, 2002 , 2021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 20.78, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Clinch River Plant Coal Assets 2021-01-012021-12-31 C000530 CENTERVILLE - VA, Transmission, , 138, 13.09, , 10.5,  2021-01-012021-12-31 C000530 PENHOOK - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 KENOVA - WV, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 Franchise Tax, NC, 2017 , 2021-12-31 C000530 Amortization of Regulatory Debits and Credits 2021-01-012021-12-31 C000530 0571 Garden Creek, Baileysville (VA), 2, 13, 1, 636KCM ACSR, , 2021-01-012021-12-31 C000530 AG1-091 , 7705.77 2021-01-012021-12-31 C000530 0186 BAKER, KY, BROADFORD, VA, 3, 954KCM ACSR 2021-01-012021-12-31 C000530 7539 DAN, VA, CAROLINA, , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 Other (provide details in footnote):ferc:ElectricOtherFacilitiesMember 2021-01-012021-12-31 C000530 Materials and Supplies, OPCo , 6376212.74 2021-01-012021-12-31 C000530 BELLE - WV, Transmission, , 46, 12, , 20,  2021-01-012021-12-31 C000530 Other Minor Projects under $1,000,000 2021-01-012021-12-31 C000530 RENSFORD - WV, Distribution, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 0006 KANAWHA, WV, SPORN, WV, 3, 0, 1, 1414KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLOVERDALE EAST 500KV - VA, Transmission, , 500, 345, 13.8, 3500,  2021-01-012021-12-31 C000530 0083 RAVENSWOOD, WV, SPORN #3, WV, 3, 1, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Glen Lyn Ash Pond ARO - VA HB443 2021-01-012021-12-31 C000530 BIM - WV, Transmission, , 138, 69, 46, 84,  2021-01-012021-12-31 C000530 Central Machine Shop, SWEPCo , 2683567 2021-01-012021-12-31 C000530 Defd Carrying Charges - Reliability Capital - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2020-12-31 C000530 BROOKVILLE - VA, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 SFAS 109 Deferred State Income Tax 2021-01-012021-12-31 C000530 Income Tax, WV, 2018 , 2021-12-31 C000530 0394 GRAVES MILLS LOOP, VA, , 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Property Taxes - Capital Leases West Virginia 2020-12-31 C000530 ferc:ElectricUtilityMember Corp Prgrm Billing - APCO Tran 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 12, , 7.5,  2021-12-31 C000530 CECL adoption of ASC 326 2020-01-012020-12-31 C000530 CAPITOL HILL 46KV - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, , 13.8, 250,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA (A), Transmission, , 138, 70.5, 13.09, 78,  2021-12-31 C000530 TULTEX - VA, Distribution, , 34.5, 7.2, , 5,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember WS-CI-APCo-G PPB 2021-01-012021-12-31 C000530 Virginia Triennial Appeal 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 12, , 9.38,  2021-01-012021-12-31 C000530 DAN RIVER RESEARCH - VA, Distribution, , 12, 0.6, , 0.25,  2021-01-012021-12-31 C000530 SPRING CREEK - VA, Distribution, , 138, 13.09, , 21,  2021-01-012021-12-31 C000530 ferc:UnemploymentTaxMember 2021-12-31 C000530 , T Line Robots - Reclass 2021-01-012021-12-31 C000530 AG1-540 , 662.51 2021-01-012021-12-31 C000530 335 - London Hydro, 517000, 0.0266 2021-01-012021-12-31 C000530 Carbon Capture and Storage Project FEED Study Costs - Rate Order: WV PSC Case 13-0467-E-GI 2021-12-31 C000530 JEWELL RIDGE - VA, Distribution, , 69, 12, , 9.38,  2021-12-31 C000530 PINE GAP - WV, Distribution, , 46, 12, , 3,  2021-01-012021-12-31 C000530 0071 CABIN CREEK, WV, TURNER #2, WV, 3, 0, 1, 250KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0106 CLAYTOR, VA, GLEN LYN #2, VA, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ROANOKE ELECTRIC STEEL - VA, Distribution, , 138, 34.5, , 197,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 765, 345, 34.5, 5400,  2021-12-31 C000530 SHERWILL - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 IPP - System Upgrade Credits 2021-01-012021-12-31 C000530 362 - VA, 412908000, 0.0232 2021-01-012021-12-31 C000530 0109 MORGANS CUT LOOP, VA, , 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 401 - Operation Expense - Nonassociated 2021-01-012021-12-31 C000530 0346 PINE CREEK TAP, WV, , 1, 2, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0223 BRADLEY CIR B, WV, GLEN LYN-HINTON, VA, 3, 43, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 13.09, 34.5, 500,  2021-12-31 C000530 CLOVERDALE 765KV - VA (H), Transmission, , 138, 70.5, 36.2, 78,  2021-12-31 C000530 Property Tax, OH, 2021 , 2021-01-012021-12-31 C000530 BLUE RIDGE - VA, Distribution, , 34.5, 12, , 10.94,  2021-12-31 C000530 PAX BRANCH 138KV - WV, Transmission, , 138, 46, , 216,  2021-12-31 C000530 SHARPLES - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 RAGLAND - WV, Distribution, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember SS-CI-APCo-D GEN PLT 2021-12-31 C000530 SCOTTSVILLE (AP) - VA, Transmission, , 46, 13.09, , 9.38,  2021-01-012021-12-31 C000530 HALES BRANCH - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 Franchise Tax, TN, 2017 , 2021-12-31 C000530 GRUNDY - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 HARTLAND - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 SKIMMER - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 Other State Tax, OH, 2021 , 16687 2021-01-012021-12-31 C000530 AE1-064 , 4899.32 2021-01-012021-12-31 C000530 0310 CLOVERDALE, VA, JOSHUA FALLS, VA, 3, 57, 1, 1351KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0067 JOHNS CREEK, KY,  SPRIGG, WV, 1, 1, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CAPITOL HILL 138KV - WV, Transmission, , 138, 46, , 45,  2021-12-31 C000530 ferc:ElectricUtilityMember Accrued Book ARO Expenses 2021-01-012021-12-31 C000530 PLANT ROAD - WV, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 Franchise Tax, NC, 2018 , 2021-01-012021-12-31 C000530 Unrealized Loss on Forward Commitments 2021-12-31 C000530 0183A BAKER, KY, CULLODEN, WV, 3, 34, 1, 954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 DUQUESNE LIGHT COMPANY, OS, NOTE 1 2021-01-012021-12-31 C000530 HANCOCK - VA, Transmission, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 312 - Amos U1&2, 1376120000, P61Y, 0.0391 2021-01-012021-12-31 C000530 MERRIMAC - VA, Transmission, , 138, 69, 13.09, 78,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/Danville - Martinsville T 2021-12-31 C000530 0031 BRADLEY, WV, KANAWHA #1, WV, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Ed-Ci-Apco-D Cust Serv 2021-12-31 C000530 Defd System Reliability Costs - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2020-12-31 C000530 Virginia Broadband Pilot Filing 2021-01-012021-12-31 C000530 Niagara Hydro Project #2466 - Proportion of cost of administering the Federal Water Power Act 2021-12-31 C000530 BYLLESBY - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 Income Tax, VA, 2020 , 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo VA Major Eq/ Spares-Trans 2021-01-012021-12-31 C000530 BAILEYSVILLE, WV, TAZEWELL, VA, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 VA Broadband Under Recovery 2021-01-012021-12-31 C000530 0387 LOGAN, WV, WYOMING #2, WV, 3, 23, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 KUMIS - VA, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 Carbon Capture and Storage Project FEED Study Costs - Rate Order: WV PSC Case 13-0467-E-GI 2020-12-31 C000530 PEARISBURG - VA, Distribution, , 34.5, 12, , 6.25,  2021-01-012021-12-31 C000530 Franchise Tax, NC, 2020 , 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AF1-323  , -104.14 2021-01-012021-12-31 C000530 0336 CLENDENIN TAP, , 1, 8, 0, , 0, 0 2021-01-012021-12-31 C000530 ROANOKE ELECTRIC STEEL - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:SalesAndUseTaxMember 2020-12-31 C000530 Local Tax, WV, 2021 , 11076357 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Franchise Tax, NC, 2021 , 2100 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:TransmissionPlantMember 2021-01-012021-12-31 C000530 COVE ROAD - VA, Distribution, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 PJM - #AF2-105  , -260.81 2021-01-012021-12-31 C000530 Unrecovered Fuel - Common Wealth Virginia - Per Agreement with Commonwealth of Virginia. Effective June 4, 2015. 2021-12-31 C000530 NEW LONDON - VA, Transmission, , 138, 34.5, , 30,  2021-12-31 C000530 0176A HOLSTON, TN, REEDY CREEK, TN, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, VA, 2021 , 2020-12-31 C000530 LAKEVIEW - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 331 - Buck Hydro, 570000, P112Y, 0.049 2021-01-012021-12-31 C000530 GAULEY RIVER POWERS PARTNERS, OS, 2021-01-012021-12-31 C000530 FIRSTENERGY TRADING SERVICES, OS, NOTE 1 2021-01-012021-12-31 C000530 MOSS - VA, Distribution, , 69, 12, , 8.4,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA (F), Transmission, , 138, 70.5, 36.2, 78,  2021-12-31 C000530 WV Vegetation Management Program Costs - Rate Order: WV PSC Case 13-0557-E-P - Rate Order: WV PSC Case 14-1152-E-42T 2020-12-31 C000530 Netting of Trading Activities related to Unrealized Gains/Losses on Forward Commitments between Regulated Assets/Liabilities 2021-01-012021-12-31 C000530 PJM - #AD2-178  , 9052.93 2021-01-012021-12-31 C000530 Customer Deposits 2021-01-012021-12-31 C000530 AE2-160 , 2870.35 2021-01-012021-12-31 C000530 APCO Distr Pre Eng Parent 2021-01-012021-12-31 C000530 CHESTERFIELD AVENUE - WV, Transmission, , 138, 13.09, , 40,  2021-01-012021-12-31 C000530 PETERS MOUNTAIN - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 SPRIGG - WV, Transmission, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AF1-049  , -150.63 2021-01-012021-12-31 C000530 TOTAL DISTRIBUTION, 4613780000, 2021-01-012021-12-31 C000530 AG2-132 , 1420.7ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Accrued Book ARO Expenses 2020-12-31 C000530 VA Sales/Use Tax Surcharge 2021-01-012021-12-31 C000530 RIDGEWAY - VA, Transmission, , 138, 69, 7.2, 35,  2021-12-31 C000530 SMYTH - VA, Distribution, , 138, 36.2, , 30,  2021-12-31 C000530 0096 CARBIDE #8, WV, CHEMICAL-TURNER B, WV, 3, 7, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Corporate Human Resources, AEPSC , 4131451.61 2021-01-012021-12-31 C000530 GAULEY MOUNTAIN - WV, Distribution, , 69, 12, , 8.4,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Deferred Fuel Costs 2021-12-31 C000530 IVY HILL - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 WHEATLAND - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 West Virginia Environmental RAC Filing 2021-01-012021-12-31 C000530 WV Broadband Over Recovery 2021-01-012021-12-31 C000530 HILL - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0390 BELVA TAP, WV, , 3, 1, 1, 954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Accrued Book Removal Costs 2021-01-012021-12-31 C000530 PJM Network Integ Trans Serv Various Various FNO 2021-01-012021-12-31 C000530 Virginia Broadband RAC Filing 2021-12-31 C000530 PJM INTERCONNECTION, OS, 2021-01-012021-12-31 C000530 ferc:NitrogenOxideMember Wolverine Power Supply Cooperative, Inc. 2021-01-012021-12-31 C000530 Environmental Compliance Costs - Rate Orders: VA Code Section 56-582B (vi) VASCCPUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2020-12-31 C000530 FERC Formula Rate Filing 2021-12-31 C000530 0 2021-01-012021-12-31 C000530 VA Renewable Energy Portfolio Standard - VA SCC Case No. PUE-2009-00038 2021-01-012021-12-31 C000530 0006A AMOS, WV, KANAWHA, WV, 3, 28, 1, 1563KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Property Tax, NE, 2019 , 360 2021-12-31 C000530 Income Tax, IL, 2021 , 2021-12-31 C000530 1020 CLINCH RIVER, VIRGINA CITY, , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember SS-CI-APCo-T GEN PLT 2021-01-012021-12-31 C000530 Appropriations of Retained Earnings (Acct. 436) 2020-01-012020-12-31 C000530 7119 HANCOCK, VA, ROANOKE, VA TOWER 198, , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 LAKE FOREST - VA, Distribution, , 138, 36.2, , 30,  2021-12-31 C000530 ferc:ElectricUtilityMember APCO-D 2021-01-012021-12-31 C000530 ferc:GeneralPlantMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 Kanawha River Plant Demolition Filing 2021-12-31 C000530 PJM - #AF2-105  , 1013.65ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 OAK HILL (AP) - WV, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 AMOS 765KV - WV, Transmission, , 765, 138, 13.8, 750,  2021-01-012021-12-31 C000530 BANCROFT - WV, Transmission, , 138, 34.5, , 20,  2021-01-012021-12-31 C000530 0004 MUSKINGUM, WV, SPORN, WV, 3, 0, 1, 1275KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CENTRAL AVENUE (AP) - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 0382 LANHAM, WV, , 1, 1, 2, 795 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 LPS-TOD - LARGE POWER SERVICE TOD , 1709 , 153131 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Interest Expense Capitalized for Tax 2021-12-31 C000530 WALTON PARK - VA, Distribution, , 69, 2.4, , 2,  2021-12-31 C000530 JUBAL EARLY - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 INGLES - VA, Distribution, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 333 - Winfield Hydro, 7717000, 0.0332 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AG1-494  , 1559.57 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other Minor Projects under $1,000,000 2021-12-31 C000530 RIVERBEND - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ferc:LandAndRightsMember Amos-Gavin 765KV Comm Solvents Tract Land, WV (2639) 2021-01-012021-12-31 C000530 Carrying Chgs-COVID-19 Costs - VA SCC Case No. PUR-2020-00074 2021-12-31 C000530 Property Tax, WY, 2020 , 2312 2021-01-012021-12-31 C000530 DUPONT (AP) - VA, Distribution, , 69, 12, , 4.2,  2021-01-012021-12-31 C000530 Marmet and London Hydro Project #1175 - Proportion of cost of administering the Federal Water Power Act 2021-12-31 C000530 0167 CLINCH RIVER, VA, GARDEN CREEK, VA, 1, 22, 0, , 0, 0 2021-01-012021-12-31 C000530 ferc:NitrogenOxideMember 2020-12-31 C000530 335 - Niagara Hydro, 307000, 0.0885 2021-01-012021-12-31 C000530 MARTINSVILLE - VA, Transmission, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 SPRING CREEK - VA, Distribution, , 138, 13.09, , 21,  2021-12-31 C000530 WELCH - WV, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 0258 OPOSSUM CREEK, VA, PEAKSVIEW, VA, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0524 Joshua Falls 765/138kV Bus Tie No. 1, , 1, 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 34.5, , 75,  2021-12-31 C000530 ITMANN - WV, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 2,000 shares common stock 2021-12-31 C000530 ferc:ElectricUtilityMember CAPITALIZED SOFTWARE COST?BOOK 2021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, , , 250,  2021-12-31 C000530 ferc:ElectricUtilityMember Extra. Loss on Retired Plants 2021-12-31 C000530 Other State Tax, VA, 2018 , 0 2020-12-31 C000530 0211 MULLENSVILLE LOOP, WV, , 3, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0385 CAPITALIZED SPARE PART, MAX MEADOW, , 0, 1, , 0, 0 2021-01-012021-12-31 C000530 EXPRESSWAY - VA, Distribution, , 69, 12, , 42.4,  2021-01-012021-12-31 C000530 MATT FUNK 345KV - VA, Transmission, , 345, 138, 34.5, 675,  2021-01-012021-12-31 C000530 Other State Tax, VA, 2021 , 6421600 2021-12-31 C000530 0503 CLINTWOOD EXTENSION, , 1, 0, 2, 1033.5 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 NORTH CLAYTOR - VA, Transmission, , 138, 69, 34.5, 200,  2021-12-31 C000530 ferc:ElectricUtilityMember CLH 3 Tailrace Disolved Oxygen 2021-12-31 C000530 Corporate Communications, AEPSC , 1394258.68 2021-01-012021-12-31 C000530 2360105 FICA CARES ACT , Federal Insurance Tax, ,  , 0 2021-01-012021-12-31 C000530 REUSENS - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 3,000 shares common stock 2021-12-31 C000530 Undistributed earnings/losses and dividends - Central Appalachian Coal 2021-01-012021-12-31 C000530 TRAP HILL - WV, Distribution, , 46, 36.2, , 40,  2021-12-31 C000530 183 - Prelim Surveyferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C000530 Distribution Expenses - Maintenance, KgPCo , 303524 2021-01-012021-12-31 C000530 335 - Buck Hydro, 942000, 0.1445 2021-01-012021-12-31 C000530 DAN RIVER RESEARCH - VA, Distribution, , 69, 12, , 1,  2021-12-31 C000530 FOUR POLE CREEK - WV, Distribution, , 34.5, 4.16, , 4.5,  2021-01-012021-12-31 C000530 RIDGEWAY - VA, Transmission, , 138, 69, 4, 40,  2021-12-31 C000530 0405 JACKSONS FERRY, WYOMING, 3, 32, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 State Commission Fees 2021-12-31 C000530 State Commission Fees 2021-01-012021-12-31 C000530 WASENA - VA, Distribution, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 0098A FLATWOOD TAP, WV, , 3, 5, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 VA Major Storm Expense - VA SCC Case No. PUR-2020-00015 2021-12-31 C000530 PANTHER - WV, Distribution, , 46, 7.2, , 4.5,  2021-01-012021-12-31 C000530 Public Authority-Large General Svc-TOD-Pri , 100 , 9321 2021-01-012021-12-31 C000530 ferc:OtherUtilityMember 2021-12-31 C000530 ferc:ElectricUtilityMember D/AP/Capital Blanket - APCo 2021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AD1-017  , 23.82 2021-01-012021-12-31 C000530 ferc:OtherStateTaxMember 2021-12-31 C000530 344 Dresden - VA AFUDC, 6591000, 0.1951 2021-01-012021-12-31 C000530 2023 Virginia Triennial Filing 2021-12-31 C000530 Unemployment Tax, KY,  , 317 2021-12-31 C000530 1,500 shares common stock 2020-12-31 C000530 THORNTON - VA, Distribution, , 138, 13.09, , 9.38,  2021-01-012021-12-31 C000530 Various Expenses 2021-01-012021-12-31 C000530 312 - Amos U3 SCR, 18634000, P60Y, 0.0972 2021-01-012021-12-31 C000530 SHERIDAN (AP) - WV, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 13.09, , 10.5,  2021-12-31 C000530 ferc:PayrollTaxMember 2021-12-31 C000530 Excise Tax, , 2021 , 16433 2021-01-012021-12-31 C000530 Property Tax, WV, 2019 , 26137350 2020-12-31 C000530 333 - Marmet Hydro, 8696000, 0.034 2021-01-012021-12-31 C000530 0119 CLOVERDALE, VA, GLEN LYN, VA, 3, 0, 2, 795KCM ACSR, , 2021-01-012021-12-31 C000530 LICK FORK - VA, Distribution, , 69, 34.5, , 10.5,  2021-12-31 C000530 0387 LOGAN, WV, WYOMING #2, WV, 2, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0259A EAST DANVILLE, WV, EAST MONUMENT, , 4, 0, , 0, 0 2021-01-012021-12-31 C000530 MARTINSVILLE - VA, Transmission, , 138, 70.5, 36.2, 108,  2021-01-012021-12-31 C000530 Amortize KDL through Jan 2025 2021-01-012021-12-31 C000530 GRAND RIDGE ENERGY II LLC, OS, 2021-01-012021-12-31 C000530 ITMANN - WV, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 356.16, 40675000, 0.0166 2021-01-012021-12-31 C000530 RIDGEWAY - VA, Transmission, , 138, , , , REACTOR 2021-01-012021-12-31 C000530 HALES BRANCH - VA, Transmission, , 138, 69, 12, 84,  2021-01-012021-12-31 C000530 MILTON - WV, Transmission, , 138, 13.09, , 25,  2021-12-31 C000530 Allowances Usedferc:SulfurDioxideMember 2021-01-012021-12-31 C000530 MONEL - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 2123 SOUTH NEAL, WEST HUNTINGTON, 3, 2, 1, , 0, 0 2021-01-012021-12-31 C000530 SALTVILLE - VA, Transmission, , 138, 69, 34.5, 56,  2021-12-31 C000530 BASSETT - VA, Distribution, , 69, 12, , 25,  2021-12-31 C000530 COTTAGEVILLE - WV, Distribution, , 69, 12, , 6.25,  2021-01-012021-12-31 C000530 0474 COBB, WV, THOROFARE CREEK, 3, 0, 1, 795 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Lisa M. Barton, Vice President 2021-01-012021-12-31 C000530 WOOLWINE - VA, Distribution, , 69, 34.5, , 25,  2021-12-31 C000530 Capital Contributions Central Appalachian Coal Company 2021-12-31 C000530 MERRIMAC - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Income Tax, KY, 2020 , 2020-12-31 C000530 ROANOKE (AP) - VA, Transmission, , 138, 69, 12, 130,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AF2-302  , 884.42 2021-01-012021-12-31 C000530 CATAWBA - VA, Transmission, , 138, 34.5, , 30,  2021-12-31 C000530 ferc:ElectricUtilityMember APCo T (Station) 2021-12-31 C000530 CINDERELLA - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 12, , 15,  2021-12-31 C000530 Amortize through June 2026 2021-12-31 C000530 0318 M&B TAP, WV, , 1, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Unemployment Tax, VA,  , 45848 2020-12-31 C000530 332 - Claytor Hydro, 12714000, 0.0219 2021-01-012021-12-31 C000530 APCO: 2020-2021 MW Upgrades 2021-01-012021-12-31 C000530 Property Tax, OH, 2020 , 9 2021-12-31 C000530 3% 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO - T Work Supplemental 2021-01-012021-12-31 C000530 GRAVES MILL - VA, Distribution, , 138, 13.09, , 40,  2021-12-31 C000530 0170 OPOSSUM CREEK, VA, SMITH MOUNTAIN, VA, 1, 19, 0, , 0, 0 2021-01-012021-12-31 C000530 AG1-162 , 4481.69ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 13.09, 34.5, 15,  2021-12-31 C000530 ALLOY - WV, Distribution, , 46, 13.09, , 9.38,  2021-01-012021-12-31 C000530 DINGESS - WV, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 Dresden Operating Costs - VA - Rate Order: VA SCC PUE-2011-00036 2021-01-012021-12-31 C000530 SFAS 112 Postemployment Benefits - Rate Order: WV PSC Case 14-1152-E-42T 2021-01-012021-12-31 C000530 FRIES - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 SEVENTH STREET - VA, Distribution, , 69, 12, , 69.8,  2021-01-012021-12-31 C000530 HANCOCK - VA, Transmission, , 138, 34.5, 11, 45,  2021-01-012021-12-31 C000530 ferc:SulfurDioxideMember 2021-12-31 C000530 0300 DAN RIVER, NC, RIDGEWAY, VA, 1, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 INGLES - VA, Distribution, , 69, 34.5, , 50,  2021-01-012021-12-31 C000530 0253 CLOVERDALE, VA, JACKSONS FERRY, VA, 3, 65, 1, 954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0012 BAKER, KY, TRI STATE, WV, 3, 6, 1, 954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 AG2-203 , 1936.07ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 Tranche A-1, 2.0076%, Due 2024 2021-01-012021-12-31 C000530 PJM - #AG1-124  , 1452.84 2021-01-012021-12-31 C000530 PJM - #AG1-311  , 1603.39 2021-01-012021-12-31 C000530 JARROLD - WV, Distribution, , 46, 13.09, , 5,  2021-01-012021-12-31 C000530 Corporate Planning & Budgeting, AEPSC , 2019177.09 2021-01-012021-12-31 C000530 VICKER - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 CLINCHFIELD - VA, Transmission, , 138, 70.5, 36.2, 90,  2021-12-31 C000530 183 - Prelim Survey 2021-01-012021-12-31 C000530 BENT MOUNTAIN - VA, Distribution, , 138, 34, , 10.5,  2021-01-012021-12-31 C000530 PJM - #AD1-102  , 28501.76 2021-01-012021-12-31 C000530 BONSACK - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 FAS 109 Deferred State Income Tax 2021-01-012021-12-31 C000530 0322 JOSHUA FALLS, VA, REUSENS A&B, VA, 1, 0, 1, 1590KCM ACSR, , 2021-01-012021-12-31 C000530 Amos 2021-12-31 C000530 CHEMICAL - WV, Transmission, , 46, 12, , 22.4,  2021-01-012021-12-31 C000530 LAVALETTE - WV, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 HICKMAN - VA, Distribution, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/CrningGls-Rdgewy69kv:Relo 2021-12-31 C000530 0016 JIM BRANCH, YUKON, , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 RED HILL - VA, Distribution, , 138, 13.09, , 8.4,  2021-12-31 C000530 PINNACLE CREEK - WV, Distribution, , 138, 34.5, 12, 13.3,  2021-12-31 C000530 184 - Clearing Accounts 2021-01-012021-12-31 C000530 NAGEL - TN, Transmission, , 500, 138, 13.8, ,  2021-01-012021-12-31 C000530 CENTERVILLE - VA, Transmission, , 138, 13.09, , 10.5,  2021-12-31 C000530 FULKS - WV, Distribution, , 34.5, 34.5, 6.5, 30,  2021-01-012021-12-31 C000530 Rents Billed in Advance 2021-12-31 C000530 ATKINS - VA, Distribution, , 138, 34.5, 12, 9.38,  2021-01-012021-12-31 C000530 OCEANA - WV, Distribution, , 46, 12, , 16.75,  2021-01-012021-12-31 C000530 ferc:NextTwelveMonthsMemberferc:SulfurDioxideMember 2021-12-31 C000530 0297 GAVIN, OH, MOUNTAINEER, WV, 3, 8, 1, 1351KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 T.V. Pole Attachments 2021-12-31 C000530 Income Tax, IL, 2021 , 2020-12-31 C000530 CLOVERDALE 765KV - VA (E), Transmission, , 138, 70.5, 36.2, 78,  2021-12-31 C000530 ferc:ElectricUtilityMemberferc:IncomeTaxMember 2021-01-012021-12-31 C000530 RIDGEWAY - VA, Transmission, , 138, 13.09, , 9.38,  2021-01-012021-12-31 C000530 0365 DICKENS TAP, , 1, 3, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 MCROSS - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 Income Tax, WV, 2021 , 2020-12-31 C000530 Virginia Broadband RAC Filing 2021-01-012021-12-31 C000530 0ferc:Quarter4Member 2021-01-012021-12-31 C000530 ferc:AllocationOfPayrollChargedForClearingAccountsMember 184 - Clearing Accounts 2021-01-012021-12-31 C000530 333 - Byllesby Hydro, 3697000, 0.1169 2021-01-012021-12-31 C000530 ferc:OtherTaxMember 2021-12-31 C000530 0399 TANK HILL TAP, VA, , 1, 1, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ELECTRIC UTILITY RESEARCH, DEVELOPMENT & DEMONSTRATION PERFORMED EXTERNALLY, 7 Item(s) Under $50,000 2021-01-012021-12-31 C000530 Capital Contributions - Cedar Coal 2021-01-012021-12-31 C000530 SISSON - WV, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AD2-179  , 32903.4 2021-01-012021-12-31 C000530 PJM-NITS OS 2021-01-012021-12-31 C000530 Miscellaneous 2021-12-31 C000530 ferc:ElectricUtilityMember CIAC 2021-01-012021-12-31 C000530 AMERICAN ALLOYS, WV, SPORN, WV, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0538 Elk Garden Tap, , 1, 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo D Work (Supplemental) 2021-01-012021-12-31 C000530 PEMBERTON - WV, Transmission, , 46, 4, , 5,  2021-01-012021-12-31 C000530 0423 STONEWALL TAP, , 3, 1, 0, 795 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SHABDUE - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Other (Specify)ferc:OtherUtilityMember 2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 70.5, 46, 90,  2021-12-31 C000530 CANDLERS MOUNTAIN - VA, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 BARNETT - WV, Distribution, , 69, 12, , 20,  2021-12-31 C000530 Teays Valley SC Land Purchase 2021-01-012021-12-31 C000530 SCHUYLER - VA, Distribution, , 46, 7.2, , 2.01,  2021-01-012021-12-31 C000530 HOPKINS - WV, Transmission, , 138, 0, 0, 0, AIR CORE REACTOR 2021-12-31 C000530 WEST HUNTINGTON - WV, Transmission, , 138, 69, 34.5, 130,  2021-01-012021-12-31 C000530 331 - Claytor Hydro, 3863000, P102Y, 0.0308 2021-01-012021-12-31 C000530 STATE OF VIRGINIA, STATE OF VIRGINIA, , 0, , , , 2021-01-012021-12-31 C000530 Income Tax, NOL, 2011 , 2021-01-012021-12-31 C000530 3791 BOLT, WV, TRAP HILL, WV, 1, 6, 1, , 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other 2021-01-012021-12-31 C000530 0395 MONEL LOOP, VA, , 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ESMONT - VA, Distribution, , 46, 12, , 4.69,  2021-12-31 C000530 AMOS 765KV - WV, Transmission, , 138, 69, 46, 130,  2021-01-012021-12-31 C000530 PJM - #AD2-022  , -166.34ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0170 OPOSSUM CREEK, VA, SMITH MOUNTAIN, VA, 3, 15, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 2360104 FICA , Federal Insurance Tax, ,  , 0 2021-12-31 C000530 397.16, 19365000, 0.0494 2021-01-012021-12-31 C000530 PRINCETON - WV, Distribution, , 34.5, 12, , 20,  2021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, 500, 13.8, 500,  2021-01-012021-12-31 C000530 ferc:NitrogenOxideMemberferc:TwoYearsMember 2021-12-31 C000530 RIPLEY - WV, Distribution, , 69, 13.09, , 12.5,  2021-12-31 C000530 BIM - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 MCROSS - WV, Distribution, , 69, 34.5, , 30,  2021-12-31 C000530 BLAINE - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 0537 WOLF GLADE EXTENSION, , 1, 2, 2, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Mountaineer 2021-01-012021-12-31 C000530 WEST HUNTINGTON - WV, Transmission, , 138, 34.5, , 25,  2021-12-31 C000530 A(6)g Research - General:, 1 Item(s) Under $50,000 2021-01-012021-12-31 C000530 ferc:PropertyTaxMember 2020-12-31 C000530 WV Deferred Rate Case Expenses - WVPSC Case #18-0646-E-42T - Amortization Period: 03/2019 - 02/2022 2020-12-31 C000530 ferc:ElectricUtilityMember 2020-01-012020-12-31 C000530 BLACKWATER - VA, Distribution, , 34.5, 12, , 20,  2021-01-012021-12-31 C000530 0481 LAKEVIEW, 138KV EXTENSION, , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 ferc:CurrentYearMemberferc:SulfurDioxideMember 2020-12-31 C000530 BLUE RIDGE - VA, Distribution, , 12, 4, , 0.3,  2021-01-012021-12-31 C000530 STUART - VA, Distribution, , 69, 12, , 10.5,  2021-12-31 C000530 CLIFFORD - VA, Transmission, , 138, 46, , 20,  2021-01-012021-12-31 C000530 Federal Mitigation Deferral - NSR 2020-12-31 C000530 MERRIMAC - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 1,500 shares common stock 2021-01-012021-12-31 C000530 KENOVA - WV, Transmission, , 34.5, 4, , 3.75,  2021-01-012021-12-31 C000530 6,950 shares common stock 2021-12-31 C000530 WV Air Quality Permit Fees - Rate Order: WV 15-0722-E-P 2021-01-012021-12-31 C000530 Miscellaneous 2021-01-012021-12-31 C000530 SOUTH NEAL - WV, Distribution, , 69, 12, , 40,  2021-01-012021-12-31 C000530 CATAWBA - VA, Transmission, , 138, 69, 34.5, ,  2021-12-31 C000530 SCHUYLER - VA, Distribution, , 46, 7.2, , 0.83,  2021-12-31 C000530 MORGANS CUT - VA, Transmission, , 138, 69, 34.5, 200,  2021-01-012021-12-31 C000530 0296 KAMMER, WV, MOUNTAINEER, WV, 3, 1351KCM ACSR 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 345, 34.5, 15,  2021-12-31 C000530 WARD HOLLOW - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 VA RPS-RAC Over-Recovery 2021-01-012021-12-31 C000530 HUNTINGTON COURT - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 312 - Mountaineer, 1149600000, P60Y, 0.0307 2021-01-012021-12-31 C000530 316 - Centrl Mach Shop, 21795000, P0Y, 0.0263 2021-01-012021-12-31 C000530 Other Taxes, WV, 2021 , 2020-12-31 C000530 FALLING BRANCH - VA, Distribution, , 138, 13.09, , 9.38,  2021-12-31 C000530 BUCKHORN - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 Agency Fees - Factored A/R 2020-12-31 C000530 PJM - #AD2-022  , 40449.28 2021-01-012021-12-31 C000530 AG2-568 , 1534.31ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 373 - VA, 20970000, 0.0491 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember 2020-12-31 C000530 HENRY S.D. - VA, Distribution, , 34.5, 13, , 3.75,  2021-12-31 C000530 370.16 - WA, 35100000, 0.1243 2021-01-012021-12-31 C000530 SOPHIA - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 HILLSVILLE - VA, Distribution, , 34.5, 12, , 6.75,  2021-12-31 C000530 PJM - #AF2-105  , 1013.65 2021-01-012021-12-31 C000530 Income Tax, MULTI, 2019 , 2020-12-31 C000530 TOTAL OTHER, 673898000, 2021-01-012021-12-31 C000530 344 Ceredo Plant, 180621000, 0.0132 2021-01-012021-12-31 C000530 ELMO - WV, Distribution, , 69, 12, , 5,  2021-01-012021-12-31 C000530 0097 CAPITOL HILL, WV, CHEMICAL, WV, 3, 6, 2, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, WV, 2018 , 2021-01-012021-12-31 C000530 336 - Buck Hydro, 3000, 0.0244 2021-01-012021-12-31 C000530 Carrying Chgs-Capital Environmental Compliance Csts - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-01-012021-12-31 C000530 368 - WV, 244557000, 0.0465 2021-01-012021-12-31 C000530 PJM - #AG1-219  , 1784.34ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0376 DINGESS LOOP, WV, , 3, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WASENA - VA, Distribution, , 69, 13.09, , 20,  2021-12-31 C000530 Virginia Transmission RAC Filing 2021-01-012021-12-31 C000530 JOSHUA FALLS - VA, Transmission, , 765, 138, 13.8, 750,  2021-01-012021-12-31 C000530 TOMS FORK - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0, CLAYTOR 2021-01-012021-12-31 C000530 Long-Term Issuance Costs 2020-01-012020-12-31 C000530 SKIMMER - VA, Distribution, , 69, 12, , 30,  2021-12-31 C000530 341 Dresden Plant, 48517000, 0.0334 2021-01-012021-12-31 C000530 ferc:PayrollTaxMember 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA (G), Transmission, , 138, 70.5, 36.2, 78,  2021-01-012021-12-31 C000530 0470 LOCKHART, VA, , 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 RIGIS - VA, Transmission, , 138, 69, 12, 115,  2021-12-31 C000530 BAILEYSVILLE, WV, TAZEWELL, VA, 3, 9, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 AG2-368 , 1455.13 2021-01-012021-12-31 C000530 0501 JACKSONS FERRY, BUS TIE #3, 1, 0, 1, 1590 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 INDEPENDENCE - VA, Distribution, , 69, 34.5, , 20,  2021-01-012021-12-31 C000530 APCo-T Work 1ferc:ElectricUtilityMember 2021-12-31 C000530 Sales And Use Tax, VA, 2021 , 2637029 2021-01-012021-12-31 C000530 HALES BRANCH - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 336, 1052000, 0.0105 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:PropertyTaxMember 2021-01-012021-12-31 C000530 APCo-D Small Cap Adds Blkt 2021-01-012021-12-31 C000530 BARNETT - WV, Distribution, , 69, 13.09, , 20,  2021-12-31 C000530 ROANOKE (AP) - VA, Transmission, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ferc:OtherLicenseAndFeesTaxMember 2021-01-012021-12-31 C000530 TECH DRIVE - VA, Distribution, , 138, 12, , 20,  2021-12-31 C000530 BELLE - WV, Transmission, , 46, 12, , 20,  2021-12-31 C000530 DEMONSTRATION PERFORMED INTERNALLY, 2021-01-012021-12-31 C000530 PJM - #AD2-179  , -34.42ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 POINT PLEASANT - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 MAMMOTH - WV, Distribution, , 46, 12, , 3.75,  2021-01-012021-12-31 C000530 Deferred Urea Expense 2021-12-31 C000530 PUTNAM VILLAGE - WV, Distribution, , 69, 13.09, , 20,  2021-12-31 C000530 Franchise Tax, KY, 2019 , 2021-12-31 C000530 BRADLEY - WV, Transmission, , 138, 69, 46, 130,  2021-12-31 C000530 Sporn Plant 2021-01-012021-12-31 C000530 VA Distribution Substation Equity Carrying Charge Deferral 2021-12-31 C000530 PHOENIX - VA, Distribution, , 46, 7.2, , 1,  2021-01-012021-12-31 C000530 320, b, 31 2021-01-012021-12-31 C000530 354, b, 28 2021-01-012021-12-31 C000530 335, 10264000, 0.0366 2021-01-012021-12-31 C000530 MOUNT UNION - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 336 - Claytor Hydro, 32000, 0.0098 2021-01-012021-12-31 C000530 INDEPENDENCE - VA, Distribution, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 335 - Winfield Hydro, 3232000, 0.0202 2021-01-012021-12-31 C000530 341 Dresden - VA AFUDC, 951000, 0.1951 2021-01-012021-12-31 C000530 POLEYARD - WV, Distribution, , 138, 13.09, , 25,  2021-12-31 C000530 Property Tax, TN, 2020 , 1392679 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember AG1-316 , 1915.45 2021-01-012021-12-31 C000530 WIND DEFERRAL, OS, 2021-01-012021-12-31 C000530 BEECH RIDGE ENERGY LLC, OS, 2021-01-012021-12-31 C000530 PJM Network Integ Rev - Affil Various Various FNO 2021-01-012021-12-31 C000530 Income Tax, WV, 2019 , 2020-12-31 C000530 SOUTH HILLS - WV, Distribution, , 46, 12, , 22.4,  2021-12-31 C000530 0049 BAILEYSVILLE, WV, KANAWHA #2, WV, 3, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 West Virginia Base Case 2020-12-31 C000530 THORNTON - VA, Distribution, , 138, 34.5, 12, 7.5,  2021-01-012021-12-31 C000530 HARTLAND - WV, Distribution, , 46, 13.09, , 12.5,  2021-01-012021-12-31 C000530 0226 AMOS, WV, CHEMICAL #2 A, WV, 3, 8, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PJM - #AD2-178  , -31.25ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 Income Tax, TN, 2019 , 2021-01-012021-12-31 C000530 SS-CI-APCo-D GEN PLT 2021-01-012021-12-31 C000530 SWITCHBACK - WV, Transmission, , 138, 34.5, , 25,  2021-12-31 C000530 0116 CELANESE, VA, GLEN LYN, VA, 1, 4, 0, , 0, 0 2021-01-012021-12-31 C000530 RIGIS - VA, Transmission, , 138, 69, 12, 115,  2021-01-012021-12-31 C000530 0263 AMOS, WV, GAVIN, , 0, 1, , 0, 0 2021-01-012021-12-31 C000530 SPORN 345KV - WV, Transmission, , 345, 137.5, 13.8, 1350,  2021-01-012021-12-31 C000530 CABIN CREEK 46KV - WV, Transmission, , 138, 46, , 75,  2021-01-012021-12-31 C000530 Unrecovered Fuel Cost - VA 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Teays Valley SC Land Purchase 2021-12-31 C000530 ferc:NitrogenOxideMember Allowances Used 2021-01-012021-12-31 C000530 SKIMMER - VA, Distribution, , 115, 69, , 112,  2021-01-012021-12-31 C000530 PJM - #AF2-107  , -133.06 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember AMU2 Air Heater Basket Replace 2021-12-31 C000530 Customer Advance Receipts 2020-12-31 C000530 WEST BASSETT - VA, Transmission, , 34.5, 34.5, , 25,  2021-01-012021-12-31 C000530 POAGES MILL - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 ferc:TransmissionStudiesMember AG2-168 , 2068.78 2021-01-012021-12-31 C000530 0321 JOSHUA FALLS, VA, OPOSSUM CREEK, VA, 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HOPKINS - WV, Transmission, , 138, 0, 0, 0, AIR CORE REACTOR 2021-01-012021-12-31 C000530 RICHLANDS - VA, Transmission, , 138, 69, 13.1, 130,  2021-12-31 C000530 ferc:ElectricUtilityMember CAPITALIZED SOFTWARE COST?BOOK 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/Sheridan Trans CI 2021-12-31 C000530 0181 BROADFORD, VA, SULLIVAN, TN, 3, 33, 1, 2049KCM ACAR, 0, 0 2021-01-012021-12-31 C000530 0, LONDON 2021-01-012021-12-31 C000530 Charles R. Patton, Vice President 2021-01-012021-12-31 C000530 WV Felman Premium/Discount ENEC 2021-01-012021-12-31 C000530 0188 BRADFORD, VA, SULLIVAN, TN, 3, 2049KCM ACAR 2021-01-012021-12-31 C000530 SCHUYLER - VA, Distribution, , 46, 7.2, , 2.01,  2021-12-31 C000530 311 - Central Plt Maint, 86000, P0Y, 0.0202 2021-01-012021-12-31 C000530 Equity Carrying Chgs-COVID-19 Costs - VA SCC Case No. PUR-2020-00074 2021-01-012021-12-31 C000530 PJM - #AG1-194  , 1038.16 2021-01-012021-12-31 C000530 Felman , 255025 2021-01-012021-12-31 C000530 APCo T-BlnktProj Under $3M 2021-01-012021-12-31 C000530 0230 AMOS, WV, TURNER #1, WV, 3, 12, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Dresden Operating Costs - VA - Rate Order: VA SCC PUE-2011-00036 2021-12-31 C000530 Income Tax, MI, 2018 , 2021-12-31 C000530 0005 KANAWHA, WV, MATT FUNK, VA, 3, 64, 1, 2-954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0298 FLETCHERS RIDGE TAP,VA, , 1, 0, 1, 300KCM CU, 0, 0 2021-01-012021-12-31 C000530 0421 MOUNT UNION, CLOVERDALE, 2, 7, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 AG2-132 , 1420.7 2021-01-012021-12-31 C000530 ferc:ThreeYearsMemberferc:SulfurDioxideMember 2020-12-31 C000530 DARRAH - WV, Transmission, , 138, 34.5, , 45.5,  2021-01-012021-12-31 C000530 334 - Niagara Hydro, 500000, 0.1351 2021-01-012021-12-31 C000530 HYDRO, , , 2021-01-012021-12-31 C000530 THOMAS (AP) - VA, Distribution, , 34.5, 7.2, , 3,  2021-01-012021-12-31 C000530 Franchise Tax, NC, 2019 , 2021-12-31 C000530 RIVERVILLE - VA, Distribution, , 138, 13.09, , 104,  2021-01-012021-12-31 C000530 PJM - #AG1-426  , 1374.47 2021-01-012021-12-31 C000530 PRICES FORK - VA, Distribution, , , 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember U3 IP ROTOR & CYLINDER REFURBI 2021-01-012021-12-31 C000530 TOTAL HYDRO (Small Plants) 2021-12-31 C000530 ferc:PayrollTaxMember 2020-12-31 C000530 ORTIN - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 VA E-RAC Deferral AFUDC - Amortization Period: 10/2021 - 09/2022 2021-12-31 C000530 BIM - WV, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 DISMAL RIVER - VA, Distribution, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 Labor Accruals - Balance Sheet 2020-12-31 C000530 BOLT - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 0071 CABIN CREEK, WV, TURNER #2, WV, 1, 22, 0, , 0, 0 2021-01-012021-12-31 C000530 Unemployment Tax, TN,  , 2 2021-01-012021-12-31 C000530 0001CLOVERDALE, VA, LEXINGTON, VA, 3, 36, 1, 2-1780KCM ACSS, 0, 0 2021-01-012021-12-31 C000530 CITY OF RADFORD, VA, RQ, NOTE 1 2021-01-012021-12-31 C000530 0514 BEARWALLOW, FARADAY, 2, 2, 1, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 LAVALETTE - WV, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember GT1A Hot Gas Path 2021-12-31 C000530 COAL CREEK - VA, Distribution, , 69, 12, , 10,  2021-01-012021-12-31 C000530 HAMPTON - WV, Distribution, , 46, 7.2, , 4.5,  2021-12-31 C000530 MULLENS - WV, Transmission, , 138, 46, , 30,  2021-12-31 C000530 HALES BRANCH - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 INGLES - VA, Distribution, , 69, 34.5, , 50,  2021-12-31 C000530 TOTAL HYDRO (Small Plants) 2021-01-012021-12-31 C000530 MGS - MEDIUM GENERAL SERVICE , 1201 , 120070 2021-01-012021-12-31 C000530 TOMS FORK - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 West Virginia Coal Combustion Residuals and Effluent Limitation Guidelines Filing 2021-01-012021-12-31 C000530 ferc:OtherStateTaxMember 2021-01-012021-12-31 C000530 20211101-5315, 44501, ER17-405 2021-01-012021-12-31 C000530 Virginia Blue Ridge Petition Filing 2021-01-012021-12-31 C000530 A(6)f Other: Metering, 1 Item(s) Under $50,000 2021-01-012021-12-31 C000530 SKIN FORK - WV, Distribution, , 46, 12, , 8.4,  2021-12-31 C000530 ferc:ElectricUtilityMember APCO: 2020-2021 MW Upgrades 2021-01-012021-12-31 C000530 DAMERON - WV, Transmission, , 46, 34.5, , 20,  2021-01-012021-12-31 C000530 0168A BEARSKIN TAP, VA, , 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 A(7) TOTAL COST INCURRED INTERNALLY, 2021-01-012021-12-31 C000530 MILTON - WV, Transmission, , 69, 36.2, , 30,  2021-12-31 C000530 SHERIDAN (AP) - WV, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 SOUTH NEAL - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 0300 DAN RIVER, NC, RIDGEWAY, VA, 2, 4, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0302 MILTON LOOP, WV, , 3, 2, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 2021-01-012021-12-31 C000530 0110 CLAYTOR, VA, MATT FUNK, VA, 3, 30, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Interest Expense Capitalized for Tax 2020-12-31 C000530 Audit Services, AEPSC , 1563091.47 2021-01-012021-12-31 C000530 0516 RICHLANDS, WHITEWOOD, 2, 8, 1, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember CIAC 2021-12-31 C000530 0304 RUM CREEK TAP, WV, , 1, 2, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 MOSELEY - VA, Transmission, , 138, 70.5, 13.09, 1674,  2021-12-31 C000530 ferc:TransmissionStudiesMember AG1-136 , 4416.25 2021-01-012021-12-31 C000530 LEBANON - VA, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 AG1-509 , 2774.91ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0461 George Street, South Lynchburg, 1, 3, 1, 1233.6KCM ACSR/TW, 0, 0 2021-01-012021-12-31 C000530 Operating Reserves 2021-01-012021-12-31 C000530 PJM - #AG1-022  , 1733.19 2021-01-012021-12-31 C000530 CABIN CREEK 46KV - WV, Transmission, , 46, 12, , 22.4,  2021-01-012021-12-31 C000530 CHEMICAL - WV, Transmission, , 138, 69, 46, 84,  2021-12-31 C000530 Mountaineer 2021-12-31 C000530 0226 AMOS, WV, CHEMICAL 1A-2A AND 1B-2B, 3, 1, 2, 1033 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BRIDGE - WV, Distribution, , 69, 13.09, , 45,  2021-12-31 C000530 ferc:AfterThreeYearsMemberferc:SulfurDioxideMember 2020-12-31 C000530 Constellium , 170577 2021-01-012021-12-31 C000530 Property Taxes Ohio 2020-12-31 C000530 Income Tax, WV, 2017 , 2020-12-31 C000530 CLOVERDALE 765KV - VA (F), Transmission, , 138, 70.5, 36.2, 78,  2021-01-012021-12-31 C000530 CHERRY CREEK - WV, Distribution, , 138, 46, , 90,  2021-12-31 C000530 RURAL RETREAT - VA, Distribution, , 138, 34.5, , 25,  2021-12-31 C000530 350 - VA (Rights), 97601000, 0.0066 2021-01-012021-12-31 C000530 332 - Winfield Hydro, 2767000, 0.0222 2021-01-012021-12-31 C000530 ferc:ElectricPollutionControlFacilitiesMember 2020-12-31 C000530 MT HP TURBINE CP REFURBISH 2021-01-012021-12-31 C000530 Virginia Integrated Resource Plan Filing 2021-12-31 C000530 POAGES MILL - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 Lines Sold 2021-01-012021-12-31 C000530 OL-Outdoor Lighting , 67020 2021-01-012021-12-31 C000530 GLENWOOD (AP) - VA, Distribution, , 23, 12, , 3.75,  2021-12-31 C000530 LUMINAIRE TECHNOLOGIES, INC., OS, 2021-01-012021-12-31 C000530 ferc:SchedulingSystemControlAndDispatchMember 2021-01-012021-12-31 C000530 SPORN 345KV - WV, Transmission, , 345, 137.5, 13.8, 1350,  2021-12-31 C000530 Property Tax, OH, 2021 , 2021-12-31 C000530 ferc:ElectricUtilityMember CLH 4 Tailrace Disolved Oxygen 2021-12-31 C000530 LEIVASY - WV, Distribution, , 69, 12, , 8.4,  2021-01-012021-12-31 C000530 331 - Niagara Hydro, 678000, P118Y, 0.1663 2021-01-012021-12-31 C000530 HICKORY GAP - WV, Distribution, , 34.5, 12, , 2.5,  2021-01-012021-12-31 C000530 Clinch River Plant Coal Assets 2021-12-31 C000530 BRADLEY - WV, Transmission, , 46, 12, , 8.4,  2021-01-012021-12-31 C000530 DANVILLE - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 transmission line, Total shown in Column j - p, , , , , , 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA (E), Transmission, , 138, 70.5, 36.2, 78,  2021-01-012021-12-31 C000530 Netting of Trading Activities related to Unrealized Gains/Losses on Forward Commitments between Regulated Assets/Liabilities 2020-12-31 C000530 B.P. ENERGY COMPANY, OS, NOTE 1 2021-01-012021-12-31 C000530 NEW CASTLE - VA, Distribution, , 34.5, 12, , 7,  2021-12-31 C000530 MIDKIFF - WV, Distribution, , 138, 34.5, , 20,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other Minor Projects under $1,000,000 2021-01-012021-12-31 C000530 0427 EVINGTON 138KV TAP VA, , 2, 0, 0, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PJM - #AF2-382  , -167.1 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember CAPITALIZED SOFTWARE COST?BOOK 2020-12-31 C000530 TURNER - WV, Transmission, , 138, 69, 46, 84,  2021-12-31 C000530 RADFORD - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 Virginia Clean Economy Act Filing 2021-01-012021-12-31 C000530 BASSETT WALKER - VA, Distribution, , 34.5, 7.2, , 5.64,  2021-12-31 C000530 AG1-540 , 662.51ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0054 GARDEN CREEK, VA, HALES BRANCH, VA, 1, 7, 0, , 0, 0 2021-01-012021-12-31 C000530 , , ,  , 2021-01-012021-12-31 C000530 , EPRI Environmental Science 2021-01-012021-12-31 C000530 0075 SOUTH POINT, OH, SPORN, WV, 3, 10, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Federal Mitigation Deferral - NSR 2021-01-012021-12-31 C000530 HUNTINGTON COURT - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 0369 BLAINE, VA, WESTLAKE, 3, 11, 1, 1033.5 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Equity Carrying Chgs-VA Broadband Pilot - VA SCC Case No. PUR-2019-00145 2021-12-31 C000530 366 - WV, 63280000, 0.0173 2021-01-012021-12-31 C000530 2020 PJM Transmission True-Up - VA SCC Case No. PUR-2020-00015 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Book Pension Expense 2021-12-31 C000530 ferc:ElectricUtilityMemberferc:SteamProductionPlantMember 2021-01-012021-12-31 C000530 Associated Business Development 2020-12-31 C000530 Amortize IRU through May 2021 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Property Tax, OH, 2020 , 9 2021-01-012021-12-31 C000530 0415 CLIFFTOP TAP, WV, , 3, 3, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Common Stock 2021-01-012021-12-31 C000530 0001 CLOVERDALE, LEXINGTON, VA, 2, 0, 1, 2-1780kcm ACSS, 0, 0 2021-01-012021-12-31 C000530 West Virginia Coal Combustion Residuals and Effluent Limitation Guidelines Filing 2021-12-31 C000530 FRANKLIN - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 BEARWALLOW - VA, Transmission, , 138, 70.5, 13.09, 54,  2021-01-012021-12-31 C000530 0156 CLIFFORD, VA, SCOTTSVILLE, VA, 3, 29, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BASSETT WALKER - VA, Distribution, , 34.5, 7.5, , 3.75,  2021-01-012021-12-31 C000530 CHEMICAL - WV, Transmission, , 46, 12, , 22.4,  2021-12-31 C000530 HUNTINGTON COURT - VA, Distribution, , 138, 69, 34.5, 175,  2021-12-31 C000530 ferc:NitrogenOxideMemberferc:TwoYearsMember 2020-12-31 C000530 SOUTH LYNCHBURG - VA, Transmission, , 138, 69, 34.5, 50,  2021-12-31 C000530 VA RGGI Deferral 2021-01-012021-12-31 C000530 Property Tax, OH, 2020 , 9 2021-01-012021-12-31 C000530 VA Broadband Under Recovery 2021-12-31 C000530 PLANTATION PIPELINE - VA, Distribution, , 34.5, 7.5, , 4.5,  2021-01-012021-12-31 C000530 FLOYD - VA, Transmission, , 138, 13.09, , 10.5,  2021-12-31 C000530 Affiliated Intercompany Billings 2021-01-012021-12-31 C000530 GS-General Service , 23789 , 1679698 2021-01-012021-12-31 C000530 Defd System Reliability Costs - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-12-31 C000530 Federal Tax, ,  , 32552283 2021-01-012021-12-31 C000530 1050 ROCKHOUSE, , , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 0384 HINTON, WESTVACO, WV, 3, 13, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Demand Side Management Under Recovery - Rate Order: WV Public Service Commission - Case No: 10-0261-E-GI - Case No: WV PSC Case 15-0301-E-GI 2021-12-31 C000530 RIDGEWAY - VA, Transmission, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 0301 WHARTON TAP, WV, , 1, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 AXTON - VA, Transmission, , 765, , , , REACTOR 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other State Tax, VA, 2019 , -1625277 2021-01-012021-12-31 C000530 PJM trans enhancement settlement for refund 2020-12-31 C000530 Unemployment Tax, ,  , 76346 2021-12-31 C000530 TRAP HILL - WV, Distribution, , 46, 36.2, , 40,  2021-01-012021-12-31 C000530 2019-12-31 C000530 ferc:ElectricUtilityMember NIH RELICENSE NIAGARA HYDRO 2021-12-31 C000530 Customer Accounts Expenses, AEPSC , 16766025.65 2021-01-012021-12-31 C000530 204-207, g, 49 2021-01-012021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, 138, , 250,  2021-01-012021-12-31 C000530 DAN RIVER RESEARCH - VA, Distribution, , 7.62, 0.6, , 0.5,  2021-12-31 C000530 SOUTH CHRISTIANSBURG - VA, Transmission, , 138, 13.09, , 20,  2021-12-31 C000530 0358 AXTON, VA, DANVILLE #1-A, VA, 3, 0, 1, 336 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember 10% 2021-01-012021-12-31 C000530 CAVE SPRING - VA, Distribution, , 138, 13.09, , 42.4,  2021-12-31 C000530 VAN - WV, Distribution, , 69, 12, , 6.25,  2021-12-31 C000530 0352 NAGEL, TN, REEDY CREEK, TN, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CHAUNCEY - WV, Transmission, , 138, 46, 19.5, 30,  2021-01-012021-12-31 C000530 HOPKINS - WV, Transmission, , 138, 34.5, , 20,  2021-01-012021-12-31 C000530 BOONSBORO - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 Clinch River 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:PayrollTaxMember 2021-01-012021-12-31 C000530 Unemployment Tax, KY,  , 317 2021-01-012021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, 138, 13.8, 1750,  2021-01-012021-12-31 C000530 PJM Interconnection LLC - Attachment H-14, ER17-405 2021-01-012021-12-31 C000530 CLIFFORD - VA, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 ABINGDON - VA, Transmission, , 138, 13.09, , 22.4,  2021-12-31 C000530 Other Deferred Credits 2020-12-31 C000530 WHETSTONE BRANCH - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 A(3) Distribution:, 1 Item(s) Under $50,000 2021-01-012021-12-31 C000530 Unemployment Tax, ,  , 76346 2021-01-012021-12-31 C000530 LOGAN - WV, Transmission, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 Unit 2 Turbine Rotors A & B 2021-01-012021-12-31 C000530 0008A KANAWHA, WV, MATT FUNK, VA, 3, 34, 0, , 0, 0 2021-01-012021-12-31 C000530 3484 COBB TAP, , 1, 0, 1, , 0, 0 2021-01-012021-12-31 C000530 MEADOW BRIDGE - WV, Distribution, , 69, 34.5, , 8.4,  2021-01-012021-12-31 C000530 MT CI SCR CATALYST 2ND LAYER 2021-01-012021-12-31 C000530 Property Tax, AL, 2021 , 6 2020-12-31 C000530 Amortize through June 2026 2020-12-31 C000530 0389 GREENBRIER LOOP, WV, , 3, 0, 1, 246KCM ACAR, 0, 0 2021-01-012021-12-31 C000530 BIG ROCK - VA, Distribution, , 34.5, 13.65, , 5,  2021-12-31 C000530 335 - Claytor Hydro, 3056000, 0.0327 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AF2-220  , -218.94 2021-01-012021-12-31 C000530 Other State Tax, VA, 2019 , -1625277 2021-12-31 C000530 Flood Walls , 211 , 14832 2021-01-012021-12-31 C000530 Other Power Supply Expenses, AEPSC , 7073148.92 2021-01-012021-12-31 C000530 SFAS 158 Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans 2020-12-31 C000530 Income Tax, MI, 2019 , 2021-01-012021-12-31 C000530 MARTINSVILLE - VA, Transmission, , 138, 34.5, , 30,  2021-12-31 C000530 Use of Jointly Owned Facility, APTCo , 1963379 2021-01-012021-12-31 C000530 GS-General Service , 883656 2021-01-012021-12-31 C000530 AG2-202 , 1776.39ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 SFAS 112 Postemployment Benefits - Rate Order: WV PSC Case 14-1152-E-42T 2021-12-31 C000530 ROANOKE (AP) - VA, Transmission, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 Tax Services, AEPSC , 1295235.37 2021-01-012021-12-31 C000530 ferc:LandAndRightsMember Amos-Gavin 765KV Comm Solvents Tract Land, WV (2639) 2021-12-31 C000530 0419 PENHOOK, VA, SMITH MOUNTAIN, VA, 3, 7, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PJM AC2-123  , 2353.41 2021-01-012021-12-31 C000530 Central Coal Company 2021-01-012021-12-31 C000530 Labor Accruals - Balance Sheet 2021-01-012021-12-31 C000530 Franchise Tax, TN, 2020 , 2021-12-31 C000530 0025 GLEN LYN, VA (B), SOUTH PRINCETON, WV, 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SKEGGS BRANCH - VA, Transmission, , 138, 69, 4, 30,  2021-12-31 C000530 Misc Adjustments ,  , 2021-01-012021-12-31 C000530 SOUTH CHARLESTON - WV, Distribution, , 46, 12, , 22.4,  2021-12-31 C000530 Income Tax, KY, 2020 , 2021-01-012021-12-31 C000530 JIM BRANCH - WV, Transmission, , 138, 69, 46, 128.8,  2021-12-31 C000530 Greenhat Default Contingency 2021-01-012021-12-31 C000530 334 - Claytor Hydro, 3103000, 0.0265 2021-01-012021-12-31 C000530 B(5) TOTAL COST INCURRED EXTERNALLY, 2021-01-012021-12-31 C000530 0512 CLOVERDALE 765, CLOVERDALE 138, 3, 0, 1, 1590KCM ACSS, 0, 0 2021-01-012021-12-31 C000530 TANK HILL - VA, Distribution, , 138, 13.09, , 40,  2021-01-012021-12-31 C000530 ELMO - WV, Distribution, , 69, 12, , 5,  2021-12-31 C000530 Property Tax, VA, 2021 , 25977518 2021-12-31 C000530 Capacity Credits 2021-01-012021-12-31 C000530 PJM AC2-123  , 2353.41ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 CLIFFTOP - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 Other State Tax, OH, 2020 , 320 2021-01-012021-12-31 C000530 POUND - VA, Distribution, , 69, 12, , 6.25,  2021-01-012021-12-31 C000530 371 - VA, 39417000, 0.0473 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Property Tax, VA, 2021 , 25977518 2021-01-012021-12-31 C000530 Income Tax, MI, 2018 , 2020-12-31 C000530 BECKLEY - WV, Distribution, , 46, 4.16, , 6.25,  2021-01-012021-12-31 C000530 A(1)b Generation: Fossil - Fuel Steam, Adv. Generation Prog. Management 2021-01-012021-12-31 C000530 Property Tax, TN, 2020 , 1392679 2021-12-31 C000530 URY - WV, Distribution, , 46, 12, , 20,  2021-01-012021-12-31 C000530 OL-Outdoor Lighting , 197 , 24167 2021-01-012021-12-31 C000530 GLADE - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 BROADFORD - VA, Transmission, , 765, 138, 13.8, ,  2021-01-012021-12-31 C000530 RICH ACRES - VA, Distribution, , 69, 34.5, , 30,  2021-01-012021-12-31 C000530 PROGRESS PARK - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 426 - Political Activitiesferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C000530 Central Appalachian Coal Company 2021-12-31 C000530 ferc:ElectricUtilityMember Franchise Tax, TN, 2021 , 2021-01-012021-12-31 C000530 0156B BREMO, VA, SCOTTSVILLE, VA, 3, 7, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Leesville Hydro Project #2210 - Proportion of cost of administering the Federal Water Power Act 2021-12-31 C000530 335 - Marmet Hydro, 703000, 0.0244 2021-01-012021-12-31 C000530 RIVERBEND - VA, Distribution, , 69, 12, , 7,  2021-12-31 C000530 PEMBERTON - WV, Transmission, , 138, 69, 46, 90,  2021-01-012021-12-31 C000530 CARSWELL - WV, Transmission, , 138, 88, 7.98, 60,  2021-01-012021-12-31 C000530 AE1-250 , 169088.76ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 Unemployment Tax, VA,  , 45848 2021-01-012021-12-31 C000530 AE1-108 , 54704.37 2021-01-012021-12-31 C000530 SLATE CREEK - VA, Distribution, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 0148 CLINCH RIVER, VA, SALTVILLE #1B, VA, 3, 26, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Sales And Use Tax, WV, 2021 , 5210147 2021-01-012021-12-31 C000530 0058 GLEN LYN, VA, WYTHE, VA, 3, 29, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SALTVILLE - VA, Transmission, , 138, 34.5, , 20,  2021-01-012021-12-31 C000530 GLAMORGAN - VA, Distribution, , 34.5, 4, , 9.38,  2021-12-31 C000530 PJM - #AE2-047  , 16425.38 2021-01-012021-12-31 C000530 Investment in Premium on Common Stock 2021-12-31 C000530 Sales And Use Tax, TN, 2021 , 1483 2021-01-012021-12-31 C000530 GENERAL PLANT, , 2021-01-012021-12-31 C000530 APCo D Work (Supplemental) 2021-01-012021-12-31 C000530 Winterplace , 1178 2021-01-012021-12-31 C000530 WV EE/DR - Company Funded - Case No. PUE-2014-00039 2021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, 138, , 250,  2021-12-31 C000530 M&S Retiring Plants - Rate Order: VA SCC PUE-2014-0026 - Rate Order: WV PSC 14-1151-E-D 2020-12-31 C000530 ROANOKE ELECTRIC STEEL - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ELK CREEK - WV, Distribution, , 46, 12, , 3.75,  2021-12-31 C000530 Income Tax, IL, 2017 , 2021-12-31 C000530 ferc:ElectricUtilityMember APCo DISTR Work 2021-12-31 C000530 0487 PIERPONT, 138KV EXTENSION, 3, 1, 1, 1033.5 KCM, 0, 0 2021-01-012021-12-31 C000530 KENOVA - WV, Transmission, , 138, 69, 34.5, 200,  2021-12-31 C000530 FRANKLIN STREET - VA, Distribution, , 34.5, 12, , 6.25,  2021-12-31 C000530 Sales And Use Tax, WV, 2020 , 661831 2021-01-012021-12-31 C000530 BAILEYSVILLE - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Other License And Fees Tax, WV, 2021 , 240 2020-12-31 C000530 APCo-T Work 2021-01-012021-12-31 C000530 Notes Payable to Associates Companies 2021-01-012021-12-31 C000530 BOWYER - WV, Distribution, , 46, 7.2, , 3,  2021-01-012021-12-31 C000530 BROADFORD - VA, Transmission, , 765, , , , REACTOR 2021-01-012021-12-31 C000530 ferc:NextTwelveMonthsMemberferc:SulfurDioxideMember 2020-12-31 C000530 FLOYD - VA, Transmission, , 138, 12, , 9.38,  2021-01-012021-12-31 C000530 SFAS 109 Deferred Federal Income Tax 2021-12-31 C000530 RAVENSWOOD - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 CLENDENIN - WV, Transmission, , 138, 46, , 125,  2021-12-31 C000530 2360105 FICA CARES ACT , Federal Insurance Tax, ,  , 0 2020-12-31 C000530 APCo T (Station) 2021-01-012021-12-31 C000530 PATRIOT CENTRE - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 AG1-124 , 1372.52 2021-01-012021-12-31 C000530 188 - Research & Development 2021-01-012021-12-31 C000530 APPLE GROVE - WV, Transmission, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 ferc:OperatingUtilityMember 2021-01-012021-12-31 C000530 0492 TRI-STATE, TWELVEPOLE CREEK, 3, 1, 2, 795 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 FAS 109 Deferred Federal Income Tax 2020-12-31 C000530 NORTH CLAYTOR - VA, Transmission, , 138, 69, 34.5, 84,  2021-12-31 C000530 ELK GARDEN - VA, Distribution, , 138, 13.09, , 7.5,  2021-12-31 C000530 CHERRY CREEK - WV, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 HOPKINS FORK - WV, Distribution, , 46, 7.2, , 2.49,  2021-01-012021-12-31 C000530 Other Operating Revenues, OPCo , -923114 2021-01-012021-12-31 C000530 Local Tax, WV, 2020 , 3017048 2021-12-31 C000530 Capital Contributions Central Appalachian Coal Company 2020-12-31 C000530 Franchise Tax, WV, 2002 , 2021-12-31 C000530 RIPLEY - WV, Distribution, , 138, 69, 13.09, 78,  2021-12-31 C000530 UNITED FUEL GAS COMPANY - WV, Distribution, , 69, 4, , 6.25,  2021-01-012021-12-31 C000530 358.16, 7891000, 0.047 2021-01-012021-12-31 C000530 PANTHER - WV, Distribution, , 46, 7.2, , 4.5,  2021-12-31 C000530 SOUTH LYNCHBURG - VA, Transmission, , 138, 13.09, , 40,  2021-12-31 C000530 ferc:TransmissionStudiesMember AG2-368 , 1455.13 2021-01-012021-12-31 C000530 Unemployment Tax, WV,  , 194703 2021-01-012021-12-31 C000530 TANK HILL - VA, Distribution, , 138, 13.09, , 40,  2021-12-31 C000530 TURKEY PEN - VA, Distribution, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 333 - London Hydro, 8376000, 0.0299 2021-01-012021-12-31 C000530 Franchise Tax, NC, 2017 , 2021-01-012021-12-31 C000530 INGLES - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:ElectricUtilityMember APCO-Tranco Line Rebuild-T 2021-12-31 C000530 Virginia Generation RAC Filing 2021-12-31 C000530 Estimated Barging Bills 2020-12-31 C000530 0191 BROADFORD, VA, NAGEL, TN, 3, 45, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Sales And Use Tax, WV, 2021 , 5210147 2021-12-31 C000530 CRAIG-BOTETOURT ELECTRIC COOP, RQ, NOTE 1 2021-01-012021-12-31 C000530 PAD FORK - WV, Distribution, , 138, 34.5, , 20,  2021-12-31 C000530 WARD HOLLOW - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0343 STONE BRANCH TAP, WV, , 1, 6, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 MCDOWELL - WV, Transmission, , 34.5, 13.2, , 7.5,  2021-01-012021-12-31 C000530 Other State Tax, VA, 2020 , 952200 2020-12-31 C000530 SFAS 158 Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans 2021-01-012021-12-31 C000530 ferc:ExciseTaxMember 2021-12-31 C000530 ferc:ElectricUtilityMember Ed-Ci-Apco-D Ast Imp 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Ed-Ci-Apco-D Cust Serv 2021-01-012021-12-31 C000530 ELK GARDEN - VA, Distribution, , 138, 13.09, , 7.5,  2021-01-012021-12-31 C000530 PJM Point to Point Trans Serv Various Various LFP 2021-01-012021-12-31 C000530 0ferc:NovemberMember 2021-01-012021-12-31 C000530 Other (provide details in footnote): 2021-01-012021-12-31 C000530 ferc:PropertyTaxMember 2021-12-31 C000530 AXTON - VA, Transmission, , 765, , , , REACTOR 2021-12-31 C000530 SHERWILL - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 DEARINGTON - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 PJM - #AE2-292  , -18.44ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0312 BRUSH TAVERN TAP, VA, , 1, 3, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SOUTH HILLS - WV, Distribution, , 46, 13.09, , 25,  2021-01-012021-12-31 C000530 SOUTH LYNCHBURG - VA, Transmission, , 138, 70.5, 36.2, 78,  2021-01-012021-12-31 C000530 370.16 - VA, 93017000, 0.0814 2021-01-012021-12-31 C000530 CENTRAL MACHINE SHOP - WV, Distribution, , 46, 4, , 3.75,  2021-12-31 C000530 FERC Formula Rate Filing 2021-01-012021-12-31 C000530 6,950 shares common stock 2021-01-012021-12-31 C000530 Construction Services, OPCo , 1809573.14 2021-01-012021-12-31 C000530 ROBINSON - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 PJM - #AF2-220  , -218.94 2021-01-012021-12-31 C000530 STOTESBURY - WV, Distribution, , 138, 13.09, , 10.5,  2021-12-31 C000530 Glen Lyn Unit 6 2021-12-31 C000530 0, BYLLESBY 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO: 2021 - 2023 RBB LOGAN & 2021-12-31 C000530 PJM - Trans Owner Serv OS 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO Next Generation Radio Sys 2021-12-31 C000530 Netting of Trading Activities related to Unrealized Gains/Losses on Forward Commitments between Regulated Assets/Liabilities 2021-12-31 C000530 HANCOCK - VA, Transmission, , 34.5, 36.2, , 15,  2021-12-31 C000530 ferc:ElectricUtilityMember DSIT ENTRY - NORMALIZED 2021-01-012021-12-31 C000530 PEAK CREEK - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AE1-130  , 1228.37 2021-01-012021-12-31 C000530 Income Tax, IL, 2020 , 2020-12-31 C000530 State DITC 2021-01-012021-12-31 C000530 0101 DEXTER, OH, SPORN CIR A, WV, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Income Tax, TN, 2021 , 147400 2021-01-012021-12-31 C000530 PEAKSVIEW - VA, Transmission, , 138, 69, 34.5, 130,  2021-12-31 C000530 Paul Chodak, Vice President 2021-01-012021-12-31 C000530 RIDGEWAY - VA, Transmission, , 138, 69, 7.2, 35,  2021-01-012021-12-31 C000530 BOONE - WV, Distribution, , 46, 12, , 4.69,  2021-01-012021-12-31 C000530 (Increase) Decrease in other special deposits 2021-01-012021-12-31 C000530 TOTAL GENERAL PLANT, 344909000, 2021-01-012021-12-31 C000530 Reliability First FAC-003 2021-01-012021-12-31 C000530 Increases (Decreases) from Sales of Donations Received from Stockholders 2021-01-012021-12-31 C000530 WV Recycle , 10138 2021-01-012021-12-31 C000530 RONDA - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 , 1 Item(s) Under $50,000 2021-01-012021-12-31 C000530 Other Taxes, WV, 2021 , 2021-01-012021-12-31 C000530 FICA 2021 , Federal Insurance Tax, ,  , 15810857 2021-01-012021-12-31 C000530 BROADFORD - VA, Transmission, , 765, 138, 13.8, ,  2021-12-31 C000530 CHESTERFIELD AVENUE - WV, Transmission, , 138, 70.5, 46, 90,  2021-01-012021-12-31 C000530 , , ,  , 2021-12-31 C000530 GAULEY MOUNTAIN - WV, Distribution, , 69, 12, , 8.4,  2021-12-31 C000530 HICKORY GAP - WV, Distribution, , 34.5, 12, , 2.5,  2021-12-31 C000530 Income Tax, TN, 2021 , 147400 2020-12-31 C000530 ATKINS - VA, Distribution, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 PAD FORK - WV, Distribution, , 138, 34.5, , 20,  2021-01-012021-12-31 C000530 ferc:TwoYearsMemberferc:SulfurDioxideMember 2021-12-31 C000530 CITY OF SALEM, VA, RQ, NOTE 1 2021-01-012021-12-31 C000530 PEARISBURG - VA, Distribution, , 34.5, 12, , 6.25,  2021-12-31 C000530 PJM - #AG1-136  , 1317.78ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 RICH CREEK - WV, Distribution, , 46, 12, , 10.5,  2021-12-31 C000530 Other Operating Revenues, OPCo , -1078555 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Book Pension Expense 2020-12-31 C000530 0024 SPEEDWAY TAP, WV, , 1, 7, 0, , 0, 0 2021-01-012021-12-31 C000530 Other State Tax, VA, 2020 , 952200 2021-01-012021-12-31 C000530 PEAKLAND - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 AG1-092 , 5650.7ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 ORCHARD - VA, Distribution, , 34.5, 12, , 6.25,  2021-01-012021-12-31 C000530 STUART - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 DARRAH - WV, Transmission, , 138, 34.5, , 45.5,  2021-12-31 C000530 Property Tax, AL, 2021 , 6 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO Next Generation Radio Sys 2021-01-012021-12-31 C000530 TEAYS - WV, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 Unemployment Tax, WV,  , 194703 2021-12-31 C000530 0472 MERRITS CREEK, WV, , 3, 4, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 EXPRESSWAY - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 CATAWBA - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 OTHER GENERATION, , 2021-01-012021-12-31 C000530 Property Taxes West Virginia 2021-12-31 C000530 394, 41262000, 0.0263 2021-01-012021-12-31 C000530 NORTH BLACKSBURG - VA, Transmission, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 PJM - #AE1-176  , -22.03 2021-01-012021-12-31 C000530 STONE BRANCH - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember SS-CI-APCo-T GEN PLT 2021-12-31 C000530 RAVENSWOOD - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Hydraulic Power Generation - Maintenance, AEPSC , 994942.92 2021-01-012021-12-31 C000530 SCARBRO - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 NORTH BLACKSBURG - VA, Transmission, , 138, 69, 12, 128.8,  2021-01-012021-12-31 C000530 Property Tax, WY, 2020 , 2312 2021-12-31 C000530 Income Tax, VA, 2021 , 2021-01-012021-12-31 C000530 334 - Byllesby Hydro, 1081000, 0.0718 2021-01-012021-12-31 C000530 PAX BRANCH 138KV - WV, Transmission, , 138, 13.09, , 20,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 13.09, , 20,  2021-12-31 C000530 Under Recovery of PJM True-Up 2020-12-31 C000530 Income Tax, MULTI, 2019 , 2021-01-012021-12-31 C000530 MARMET - WV, Distribution, , 46, 12, , 7,  2021-01-012021-12-31 C000530 183 - Prelim Surveyferc:AllocationOfPayrollChargedForClearingAccountsMember 2021-01-012021-12-31 C000530 APCO: 2021 - 2023 RBB LOGAN & 2021-01-012021-12-31 C000530 0484 HORSEPEN, 138KV EXTENSION, , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 AMHERST - VA, Distribution, , 69, 13.09, , 25,  2021-12-31 C000530 PJM - #AF1-323  , -95.21 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember DSIT Normalized 2021-01-012021-12-31 C000530 NAGEL - TN, Transmission, , 138, 34.5, , 30,  2021-12-31 C000530 PACKSVILLE - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 PJM - #AE2-280  , -63.09 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Property Tax, WV, 2019 , 26137350 2021-01-012021-12-31 C000530 PATRIOT CENTRE - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 DAMASCUS - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 0180 HOLSTON, TN, WALTERS, NC, 3, 65, 1, 250KCM CU, 0, 0 2021-01-012021-12-31 C000530 ferc:LocalTaxMember 2021-12-31 C000530 333, 78241000, 0.0338 2021-01-012021-12-31 C000530 DSIT Normalized 2021-01-012021-12-31 C000530 OAK HILL (AP) - WV, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 T.V. Pole Attachments 2021-01-012021-12-31 C000530 SGS-TOD-Small General Service , 3160 2021-01-012021-12-31 C000530 363 - WV, 5333000, 0.0738 2021-01-012021-12-31 C000530 GLEN LYN - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Distribution Expenses - Operation, KgPCo , 300183.78 2021-01-012021-12-31 C000530 EAST DANVILLE - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0357 GRASSY FALLS, WV, MCCLUNG, WV, 1, 0, 1, 954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 T/AP/Roanoke to Kingsport Tele 2021-01-012021-12-31 C000530 Property Tax, CO, 2020 , 4861 2021-01-012021-12-31 C000530 Franchise Tax, WV, 2002 , 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Sales And Use Tax, OH, 2020 , 2267 2021-01-012021-12-31 C000530 HUGHESTON - WV, Distribution, , 46, 2.4, , 2.5,  2021-01-012021-12-31 C000530 Sales And Use Tax, OH, 2021 , 115350 2020-12-31 C000530 RICHLANDS - VA, Transmission, , 138, 69, 13.09, 78,  2021-01-012021-12-31 C000530 0248 CLAYTOR, VA, FIELDALE, 1, 38, 0, , 0, 0 2021-01-012021-12-31 C000530 Misc Exp - items less than $25,000 2021-01-012021-12-31 C000530 WAYNE - WV, Distribution, , 34.5, 13.09, , 10.5,  2021-12-31 C000530 Franchise Tax, NC, 2019 , 2020-12-31 C000530 Defd Carrying Charges - Reliability Capital - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-12-31 C000530 353, 2013345000, 0.0252 2021-01-012021-12-31 C000530 AXTON - VA, Transmission, , 765, 138, 13.8, 750,  2021-12-31 C000530 0124 CLOVERDALE, VA, SMITH MOUNTAIN, VA, 3, 32, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLINCHFIELD - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 HUFFMAN - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Tranche A-1, 2.0076%, Due 2024 2021-12-31 C000530 ferc:ElectricUtilityMember Deferred Fuel Costs 2020-12-31 C000530 ferc:ElectricUtilityMember Franchise Tax, WV, 2002 , 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Federal Tax, ,  , 32552283 2021-01-012021-12-31 C000530 ABERT - VA, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 EAST DANVILLE - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 0119 CLOVERDALE, VA, GLEN LYN, VA, 1, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AE2-280  , 154449.34 2021-01-012021-12-31 C000530 DISTRIBUTION, , 2021-01-012021-12-31 C000530 0161 CLOVERDALE, VA, ROANOKE, VA, 3, 16, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Glen Lyn Ash Pond ARO - VA HB443 2020-12-31 C000530 AG1-468 , 1900.52 2021-01-012021-12-31 C000530 APCO-D 2021-01-012021-12-31 C000530 HOPKINS, WV, LOGAN, WV, 3, 8, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0486 PAX BRANCH, 138KV EXTENSION, 3, 1, 2, 1033.5 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 361-373 - TN, 47000, 0.04 2021-01-012021-12-31 C000530 Income Tax, IL, 2019 , 2021-12-31 C000530 MEADOWVIEW - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 Income Tax, IL, 2019 , 2021-01-012021-12-31 C000530 0228 AMOS, WV, HOPKINS, WV, 3, 2, 1, 1590KCM ACSR/MA, 0, 0 2021-01-012021-12-31 C000530 ferc:CurrentYearMemberferc:SulfurDioxideMember 2021-12-31 C000530 Income Tax, MI, 2019 , 2021-12-31 C000530 0334 AXTON, VA, JACKSONS FERRY, VA, 3, 73, 1, 1351KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 VA T-RAC Costs - VA SCC Case No. PUE-2009-00031 2020-12-31 C000530 MOUNT UNION - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 DAMERON - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 AG1-162 , 4481.69 2021-01-012021-12-31 C000530 Other (provide details in footnote): 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO Distr Pre Eng Parent 2021-12-31 C000530 CABIN CREEK 46KV - WV, Transmission, , 46, 12, , 22.4,  2021-12-31 C000530 ROANOKE (AP) - VA, Transmission, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 2360105 FICA CARES ACT , Federal Insurance Tax, ,  , 0 2021-12-31 C000530 0118 CLOVERDALE, VA, MATT FUNK, VA, 3, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Items under $250,000 2021-01-012021-12-31 C000530 PJM - #AG1-091  , -726.11 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember AG1-124 , 1372.52 2021-01-012021-12-31 C000530 WAYNE - WV, Distribution, , 34.5, 12, , 5,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/Charleston to Roanoke Tel 2021-01-012021-12-31 C000530 Strategy & Transformation, AEPSC , 1227453.62 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 765, 528, 13.8, 1950,  2021-12-31 C000530 WURNO - VA (A), Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 0356 PEMBERTON TAP, WV, , 2, 1, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 333 - Leesville Hydro, 3764000, 0.0202 2021-01-012021-12-31 C000530 PJM INTERCONNECTION, OS, NOTE 1 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo-T Work 2021-01-012021-12-31 C000530 LUKENS - VA, Distribution, , 69, 13.09, , 20,  2021-12-31 C000530 SLATE CREEK - VA, Distribution, , 69, 13.09, , 20,  2021-12-31 C000530 TOTAL HYDRO PUMPED, 150818000, 2021-01-012021-12-31 C000530 0538 Elk Garden Tap, , 2, 2021-01-012021-12-31 C000530 CARBONDALE - WV, Transmission, , 138, 69, 46, 128.8,  2021-01-012021-12-31 C000530 CEDAR GROVE (AP) - WV, Distribution, , 46, 12, , 5,  2021-01-012021-12-31 C000530 PRICES FORK - VA, Distribution, , , 0, 0, 0, STATCAP 2021-12-31 C000530 PJM - #AF2-302  , -167.92 2021-01-012021-12-31 C000530 ferc:SulfurDioxideMember 2020-12-31 C000530 0539 TRI-STATE 345KV - 138KV BUS TIE NO. 1, , 3, 0, 1, 2-1590KCM ACSR, , 2021-01-012021-12-31 C000530 LONESOME PINE - VA, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 B(1) Research Support to Elec. Research Council & Elec. Power Research Inst., EPRI Research Portfolio 2021-01-012021-12-31 C000530 PROGRESS PARK - VA, Distribution, , 138, 36.2, , 30,  2021-01-012021-12-31 C000530 T.V. Pole Attachments 2020-12-31 C000530 0388 TECH DRIVE, 138KV EXTENSION, 3, 0, 1, 1590 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 NORTH POINTE - WV, Distribution, , 138, 34.5, , 20,  2021-12-31 C000530 Property Tax, AR, 2020 , 3078 2021-01-012021-12-31 C000530 AG2-190 , 391.91 2021-01-012021-12-31 C000530 Byllesby Buck Hydro Project #2514 - Proportion of cost of administering the Federal Water Power Act 2021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 138, 70.5, 36.2, 200,  2021-01-012021-12-31 C000530 0241 HUFFMAN, VA, WYTHE, VA, 1, 37, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Accrued Book ARO Expenses 2021-01-012021-12-31 C000530 GUTHRIE - WV, Distribution, , 46, 34.5, , 25,  2021-12-31 C000530 FRIES - VA, Distribution, , 69, 12, , 10.28,  2021-01-012021-12-31 C000530 THORNTON - VA, Distribution, , 138, 13.09, , 9.38,  2021-12-31 C000530 0367 BURLINGTON HEIGHTS LOO, , 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Corp Prgrm Billing - APCO Tran 2021-12-31 C000530 Capital Contributions - Southern Appalachian Coal Company 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 ST. ALBANS - WV, Distribution, , 138, 13.09, , 50,  2021-12-31 C000530 0106 CLAYTOR, VA, GLEN LYN #1, VA, 3, 26, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 1072 CLENDENIN, WV, MORRIS BRANCH, 3, 2, 1, 795 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0246 BRADLEY, WV, DAMERON, WV, 1, 10, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0475 PATRIOT COAL, WV, POINT LICK, 3, 0, 1, 556.5 KCM 26/7 AC, 0, 0 2021-01-012021-12-31 C000530 0042 SALTVILLE, VA, TAZEWELL, VA, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 DAN RIVER RESEARCH - VA, Distribution, , 12, 0.6, , 0.25,  2021-12-31 C000530 ferc:ElectricUtilityMember APCo VA Major Eq/ Spares-Trans 2021-12-31 C000530 ferc:ElectricUtilityMember Ds-Ap-Virg-Ai Recloser Repl 2021-01-012021-12-31 C000530 BRUSH TAVERN - VA, Distribution, , 138, 34.5, , 60,  2021-01-012021-12-31 C000530 0322 JOSHUA FALLS, VA, REUSENS A&B, VA, 3, 0, 2, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 311 - Clinch River, 26929000, P67Y, 0.0094 2021-01-012021-12-31 C000530 PATRICK STREET - WV, Distribution, , 46, 13.09, , 20,  2021-12-31 C000530 Property Tax, OH, 2019 , 1916228ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 IVG ENERGY, LTD, OS, NOTE 1 2021-01-012021-12-31 C000530 Franchise Tax, NC, 2017 , 2020-12-31 C000530 ferc:ElectricUtilityMember MT ELG/CCR Compliance 2021-01-012021-12-31 C000530 Other State Tax, VA, 2017 , 2020-12-31 C000530 Property Taxes Ohio 2021-12-31 C000530 ferc:ElectricUtilityMember John Vaughan Truck Garage 2021-01-012021-12-31 C000530 BRIAR MOUNTAIN - WV, Distribution, , 46, 7.2, , 3,  2021-12-31 C000530 0462 MATT FUNK EXT, , 3, 5, 0, 1590 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:LocalTaxMember 2020-12-31 C000530 BLAINE - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 Customer Advance Receipts 2021-01-012021-12-31 C000530 Other (provide details in footnote): 2020-01-012020-12-31 C000530 EAST HUNTINGTON - WV, Transmission, , 138, 69, 34.5, 90,  2021-01-012021-12-31 C000530 ferc:NitrogenOxideMemberferc:ThreeYearsMember 2021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AD2-178  , 9052.93 2021-01-012021-12-31 C000530 0349 BROADFORD, VA, NAGEL, TN, 1, 0, 0, , 0, 0 2021-01-012021-12-31 C000530 PJM - #AE2-326  , 2770.71 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Amos 1&2 DSI Project 2021-12-31 C000530 WEST BASSETT - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Construction Services, KgPCo , 583838 2021-01-012021-12-31 C000530 Virginia Integrated Resource Plan Filing 2021-01-012021-12-31 C000530 Treasury & Risk, AEPSC , 2284779.24 2021-01-012021-12-31 C000530 Hydraulic Power Generation - Operation, AEPSC , 3586933.55 2021-01-012021-12-31 C000530 CAMBRIA - VA, Distribution, , 69, 13.09, , 25,  2021-01-012021-12-31 C000530 Christian T. Beam - President and Chief Operating Officer 2021-01-012021-12-31 C000530 2020-12-31 C000530 BYLLESBY - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 A(2) Transmission:, 1 Item(s) Under $50,000 2021-01-012021-12-31 C000530 0402 SISSON TAP, WV, , 1, 0, 0, , 0, 0 2021-01-012021-12-31 C000530 HURLEY - VA, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 AG1-092 , 5650.7 2021-01-012021-12-31 C000530 PRINCE - WV, Distribution, , 69, 13.09, , 5.25,  2021-12-31 C000530 ferc:ElectricUtilityMember APCO AMI Project WV 2021-01-012021-12-31 C000530 DISMAL RIVER - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 Transmission Expenses - Maintenance, AEPSC , 6042635.18 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AE2-166  , 7937.25 2021-01-012021-12-31 C000530 ferc:OtherTaxMember 2020-12-31 C000530 ELECTRIC UTILITY RESEARCH, DEVELOPMENT &, 2021-01-012021-12-31 C000530 ferc:OtherElectricUtilityMember 2020-12-31 C000530 CLOVERDALE 765KV - VA (D), Transmission, , 138, 70.5, 13.09, 78,  2021-12-31 C000530 0349 BROADFORD, VA, NAGEL, TN, 3, 13, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 KANAWHA CITY - WV, Distribution, , 46, 12, , 22.4,  2021-12-31 C000530 371 - WV, 24454000, 0.093 2021-01-012021-12-31 C000530 NORTH BLACKSBURG - VA, Transmission, , 138, 13.09, , 22.4,  2021-12-31 C000530 RENSFORD - WV, Distribution, , 138, 34.5, , 25,  2021-12-31 C000530 Misc Adjustments , 2021-01-012021-12-31 C000530 PATRICK STREET - WV, Distribution, , 46, 13.09, , 20,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/Capital Blanket - APCo 2021-12-31 C000530 PJM Trans Owner Serv Revenue Affiliated Various Various OLF 2021-01-012021-12-31 C000530 0570 SALTVILLE, KINGSPORT (TN), 3, 17, 2, 397.5KCM ACSR, , 2021-01-012021-12-31 C000530 WHARNCLIFFE - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Property Tax, AL, 2021 , 6 2021-12-31 C000530 0076 DARRAH, WV, NORTH PROCTORVILLE, OH, 3, 2, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 VA Retired Coal Plants - VA SCC Case No. PUR-2020-00015 - Amortization Period: 01/2020 - 05/2025 2021-12-31 C000530 Other State Tax, OH, 2021 , 16687 2021-12-31 C000530 AG1-194 , 1340 2021-01-012021-12-31 C000530 Purchases/Transfers:ferc:SulfurDioxideMember 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO: 2021 - 2023 RBB LOGAN & 2021-01-012021-12-31 C000530 Central Appalachian Coal Company 2021-01-012021-12-31 C000530 PJM - #AD2-022  , 40449.28ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 CABELL - WV, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 0371 PENHOOK, VA, WESTLAKE, 1, 0, 2, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WV Deferred Storm Expense 2021-01-012021-12-31 C000530 0ferc:Quarter3Member 2021-01-012021-12-31 C000530 Sales And Use Tax, VA, 2021 , 2637029 2020-12-31 C000530 Other State Tax, FIN48,  , 2020-12-31 C000530 NITRO - WV, Distribution, , 69, 12, , 20,  2021-12-31 C000530 Property Tax, OH, 2021 , 2020-12-31 C000530 Franchise Tax, NC, 2020 , 2021-12-31 C000530 0011 KYGER CREEK, WV, TRI-STATE, WV, 2, 0, 0, 2303KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SKIMMER - VA, Distribution, , 69, 12, , 30,  2021-01-012021-12-31 C000530 Construction Services, WPCo , 648264 2021-01-012021-12-31 C000530 AMBLER RIDGE - WV, Distribution, , 138, 36.2, 34.5, 72,  2021-01-012021-12-31 C000530 336 - London Hydro, 49000, 0.0119 2021-01-012021-12-31 C000530 0433 HUFFMAN, VA, WILLIS GAP, VA, 1, 14, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SUNDIAL - WV, Transmission, , 138, 69, 46, 90,  2021-01-012021-12-31 C000530 0142 EAST DANVILLE NO. 1,VA, ROXBORO, NC, 3, 8, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO AMI Project WV 2021-12-31 C000530 0017 BAILEYSVILLE, WV, TAZEWELL, VA, 3, 31, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 390, 149791000, 0.0198 2021-01-012021-12-31 C000530 BRADLEY - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 353 Dresden Plant - VA AFUDC, 873000, 0.1951 2021-01-012021-12-31 C000530 Reliability First FAC-003 2020-12-31 C000530 Sales And Use Tax, OH, 2020 , 2267 2020-12-31 C000530 0132 ROANOKE, CAROLINA, 1, 9, 0, , 0, 0 2021-01-012021-12-31 C000530 CORNING GLASS (AP) - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Corp Prgrm Billing - APCO Tran 2021-01-012021-12-31 C000530 HASH RIDGE - WV, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 Central Coal Company 2021-01-012021-12-31 C000530 Equity Carrying Chgs-VA Broadband Pilot - VA SCC Case No. PUR-2019-00145 2020-12-31 C000530 VA Distribution Substation Equity Carrying Charge Deferral 2021-01-012021-12-31 C000530 FIELDALE - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 KOPPERSTON - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 DINGESS - WV, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 Other State Tax, KY, 2019 , -2397 2021-01-012021-12-31 C000530 Contr In Aid of Constr Advance 2021-01-012021-12-31 C000530 Other State Tax, VA, 2017 , 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 765, 345, 34.5, 5400,  2021-01-012021-12-31 C000530 Excess Earnings on Hydro Licensed Projects 2021-01-012021-12-31 C000530 RAGLAND - WV, Distribution, , 138, 34.5, , 25,  2021-12-31 C000530 ferc:ElectricUtilityMember Book Pension Expense 2021-01-012021-12-31 C000530 Other Operating Revenues, PSO , -341076 2021-01-012021-12-31 C000530 Environmental Compliance Costs - Rate Orders: VA Code Section 56-582B (vi) VASCCPUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-12-31 C000530 0226 AMOS, WV, CHEMICAL #2 B, WV, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Construction Services, WVTCo , 908736 2021-01-012021-12-31 C000530 SMITH LANE - VA, Distribution, , 34.5, 12, , 6.25,  2021-01-012021-12-31 C000530 SOLITE - VA, Distribution, , 69, 12, , 5.25,  2021-01-012021-12-31 C000530 0186 BAKER, KY, BROADFORD, VA, 3, 2021-01-012021-12-31 C000530 Berry Hill Station 2021-01-012021-12-31 C000530 GREENBRIER - WV, Distribution, , 69, 13.09, , 25,  2021-01-012021-12-31 C000530 Notes Payable to Associates Companies 2020-01-012020-12-31 C000530 BAILEYSVILLE - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 0116 CELANESE, VA, GLEN LYN, VA, 3, 4, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 EAST LYNCHBURG - VA, Transmission, , 138, 69, 34.5, 196,  2021-01-012021-12-31 C000530 Kanawha Plant 2021-12-31 C000530 CHAUNCEY - WV, Transmission, , 138, 46, 19.5, 30,  2021-12-31 C000530 ROANOKE (AP) - VA, Transmission, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 ferc:LocalTaxMember 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Forestry - APCo-T 2021-12-31 C000530 ferc:ElectricUtilityMember Extra. Loss on Retired Plants 2021-01-012021-12-31 C000530 393, 2070000, 0.0188 2021-01-012021-12-31 C000530 PJM - #AE2-280  , -38.73 2021-01-012021-12-31 C000530 Income Tax, TN, 2020 , 20300 2021-12-31 C000530 Lines Sold 2020-12-31 C000530 0300 DAN RIVER, NC, RIDGEWAY, VA, 1, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0423 STONEWALL TAP, , 1, 8, 1, , 0, 0 2021-01-012021-12-31 C000530 NEW HOPE (AP) - WV, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 WESTLAKE - VA, Distribution, , 138, 34.5, , 60,  2021-01-012021-12-31 C000530 VA E-RAC Under Recovery 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember John Vaughan Truck Garage 2021-12-31 C000530 Unrealized Gain On Forward Commitments 2021-12-31 C000530 HICKMAN - VA, Distribution, , 69, 13.09, , 20,  2021-12-31 C000530 KENOVA - WV, Transmission, , 34.5, 13.09, , 9.38,  2021-01-012021-12-31 C000530 0115 CELANESE, VA, MATT FUNK, VA, 1, 2, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, WV, 2018 , 2020-12-31 C000530 HOPKINS - WV, Transmission, , 138, 13.09, , 20,  2021-12-31 C000530 ferc:TransmissionStudiesMember AG2-657 , 1277.92 2021-01-012021-12-31 C000530 TOTAL TRANSMISSION, 4154367000, 2021-01-012021-12-31 C000530 CHERRY CREEK - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 0098 CAPITOL HILL, WV, KANAWHA, WV, 3, 18, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Other State Tax, VA, 2019 , -1625277 2021-01-012021-12-31 C000530 0154 CLINCH RIVER, VA, SALTVILLE #2, VA, 3, 3, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CHEMICAL - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 0, SMITH MOUNTAIN 2021-12-31 C000530 DANVILLE - VA, Transmission, , 138, 69, 12, 115,  2021-01-012021-12-31 C000530 ALUM RIDGE - VA, Distribution, , 138, 33, 12, 9.38,  2021-01-012021-12-31 C000530 0306 INEZ, KY, LOGAN, WV, 1, 23, 0, , 0, 0 2021-01-012021-12-31 C000530 MOUNT UNION - VA, Transmission, , 69, 12, , 20,  2021-01-012021-12-31 C000530 HINTON (AP) - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Unamortized Credit Line Fees Amortization through June 2022 2020-12-31 C000530 HANCOCK - VA, Transmission, , 138, 34.5, 11, 45,  2021-12-31 C000530 ARROWHEAD - VA, Distribution, , 69, 13.09, , 12,  2021-01-012021-12-31 C000530 0245 GILBOA, WV, KANAWHA, WV, 1, 15, 0, , 0, 0 2021-01-012021-12-31 C000530 0077 MILLBROOK, OH, SPORN, WV, 3, 9, 1, 477KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SOUTH BUFFALO - WV, Distribution, , 138, 13.09, , 60,  2021-12-31 C000530 EAST DANVILLE - VA, Transmission, , 138, 69.5, 13.09, 60,  2021-01-012021-12-31 C000530 PA - PUBLIC AUTHORITY , 0.01 2021-01-012021-12-31 C000530 0ferc:JuneMember 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:HydraulicProductionPlantPumpedStorageMember 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Purchase New APCO HDQ Building 2021-01-012021-12-31 C000530 Shadwell 69KV Substation, Roanoke County, VA 10.637 acres (7662) 2021-01-012021-12-31 C000530 RS-TOD-Residential TOD , 3170 2021-01-012021-12-31 C000530 FRANKLIN - VA, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 NORTH BLACKSBURG - VA, Transmission, , 138, 69, 12, 128.8,  2021-12-31 C000530 Grid Solutions, AEPSC , 1152480.25 2021-01-012021-12-31 C000530 Income Tax, TN, 2018 , 16345 2021-01-012021-12-31 C000530 ST. ALBANS - WV, Distribution, , 138, 13.09, , 50,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AG1-124  , 1452.84 2021-01-012021-12-31 C000530 Income Tax, NOL, 2011 , 2020-12-31 C000530 ferc:NitrogenOxideMemberferc:ThreeYearsMember 2020-12-31 C000530 Income Tax, TN, 2018 , 16345 2020-12-31 C000530 RS-Residential Service , 3 2021-01-012021-12-31 C000530 0132 ROANOKE, CAROLINA, 3, 44, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember 10% 2020-12-31 C000530 KANAWHA RIVER - WV, Transmission, , 345, 138, 13.8, ,  2021-01-012021-12-31 C000530 GARDEN CREEK - VA, Transmission, , 69, 12, , 22.4,  2021-12-31 C000530 Other Debit or Cr. Items (Describe, details in footnote): 2021-01-012021-12-31 C000530 TAZEWELL - VA, Transmission, , 34.5, 12, , 6.25,  2021-01-012021-12-31 C000530 357, 17385000, 0.0297 2021-01-012021-12-31 C000530 0228 AMOS, WV, HOPKINS, WV, 3, 2, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 APCo Transmission Work 2021-01-012021-12-31 C000530 Unrealized Gain On Forward Commitments 2021-01-012021-12-31 C000530 BECKLEY - WV, Distribution, , 46, 4.16, , 6.25,  2021-12-31 C000530 HUFF CREEK - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 VAN - WV, Distribution, , 69, 12, , 6.25,  2021-01-012021-12-31 C000530 Sales And Use Tax, TN, 2019 , 112 2020-12-31 C000530 TURKEY PEN - VA, Distribution, , 69, 12, , 10.5,  2021-12-31 C000530 Unamortized Credit Line Fees Amortization through June 2022 2021-01-012021-12-31 C000530 CABELL - WV, Distribution, , 138, 36.2, , 30,  2021-12-31 C000530 0381 LAKE FOREST, VA, , 3, 3, 2, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 34.5, , 20,  2021-01-012021-12-31 C000530 Steam Power Generation - Maintenance, AEPSC , 5674766.92 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember 3% 2021-01-012021-12-31 C000530 Franchise Tax, KY, 2020 , 2021-01-012021-12-31 C000530 SALTVILLE - VA, Transmission, , 138, 13.09, , 10.5,  2021-01-012021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 20.78, 0, 0, 0, STATCAP 2021-12-31 C000530 MIDWAY (AP) - VA, Distribution, , 69, 4, , 12.25,  2021-12-31 C000530 NEW HOPE (AP) - WV, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 PINNACLE CREEK - WV, Distribution, , 138, 34.5, , 9.38,  2021-01-012021-12-31 C000530 RIVERMONT - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 0372 JEHU EXT WV, , 3, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 DISMAL RIVER - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 PINE GAP - WV, Distribution, , 46, 12, , 3,  2021-12-31 C000530 NORTH BECKLEY - WV, Distribution, , 138, 13.09, , 25,  2021-12-31 C000530 VA Demand Response Program - Rate Order: VA SCC PUE-2011-0001 2021-01-012021-12-31 C000530 HANCOCK - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0366 RUSTBURG TAP, VA, , 1, 4, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 34.5, , 75,  2021-01-012021-12-31 C000530 EAST HUNTINGTON - WV, Transmission, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 Franchise Tax, WV, 2002 , 2020-12-31 C000530 0332 WELCH TAP, WV, , 1, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HUNTINGTON COURT - VA, Distribution, , 69, 34.5, , 75,  2021-01-012021-12-31 C000530 ferc:LandAndRightsMember Sheridan 69KV Substation, Lincoln County, WV 4.947 acres (2041) 2021-12-31 C000530 VA T-RAC Costs - VA SCC Case No. PUE-2009-00031 2021-12-31 C000530 BIG ROCK - VA, Distribution, , 34.5, 13.65, , 5,  2021-01-012021-12-31 C000530 CARBONDALE - WV, Transmission, , 46, 36.2, , 10.5,  2021-12-31 C000530 FULKS - WV, Distribution, , 34.5, 13.09, , 9.38,  2021-01-012021-12-31 C000530 MILTON - WV, Transmission, , 138, 69, 34.5, 90,  2021-12-31 C000530 MULLENS - WV, Transmission, , 138, 46, , 30,  2021-01-012021-12-31 C000530 SCOTTSVILLE (AP) - VA, Transmission, , 138, 46, , 40,  2021-12-31 C000530 EDGEMONT - VA, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 Research and Other Services, AEPSC , 6590120.88 2021-01-012021-12-31 C000530 BLUE RIDGE - VA, Distribution, , 34.5, 12, , 10.94,  2021-01-012021-12-31 C000530 GS-PA -General Service -PA , 359242 , 28540986 2021-01-012021-12-31 C000530 370 - VA, 28790000, 0.0814 2021-01-012021-12-31 C000530 SOURWOOD - WV, Distribution, , 138, 13.09, , 8.4,  2021-12-31 C000530 ferc:ElectricUtilityMember Unemployment Tax, OH,  , 3204 2021-01-012021-12-31 C000530 0122 CLINCH RIVER, VA, FREMONT, VA, 3, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Assessment 2021-01-012021-12-31 C000530 0185 BAKER, KY, BROADFORD, VA, 3, 4, 1, 954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BECCO - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 0337 BLUEFIELD, WV, SOUTH PRINCETON, WV, 1, 0, 2, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, MI, 2021 , 2021-12-31 C000530 Sales And Use Tax, OH, 2021 , 115350 2021-01-012021-12-31 C000530 SMITH LANE - VA, Distribution, , 34.5, 12, , 6.25,  2021-12-31 C000530 Other Accounts (Specify, provide details in footnote): 2021-01-012021-12-31 C000530 Tranche A-2, 3.7722%, Due 2031 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo AMI Project VA 2021-01-012021-12-31 C000530 0ferc:FebruaryMember 2021-01-012021-12-31 C000530 HOPKINS, WV, LOGAN, WV, 3, 19, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PJM - #AF2-106  , 1376.21 2021-01-012021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 138, 36.2, , 30,  2021-12-31 C000530 SEC File 70-5144, 3-23-72 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo-D Small Cap Adds Blkt 2021-01-012021-12-31 C000530 Income Tax, MI, 2017 , 2020-12-31 C000530 Unrealized Loss on Forward Commitments 2021-01-012021-12-31 C000530 Misc Exp - items less than $25,000 2021-12-31 C000530 APCo T Work 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo Distribution Work 2021-01-012021-12-31 C000530 0096 CARBIDE #8, WV, CHEMICAL-TURNER B, WV, 3, 1, 2, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 NITRO - WV, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 Southern Appalachian Coal Company 2021-01-012021-12-31 C000530 PJM Network Integ Trans Rev Whlsle Various Various FNO 2021-01-012021-12-31 C000530 HAYSI - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 Winfield Hydro Project #1290 - Proportion of cost of administering the Federal Water Power Act 2021-12-31 C000530 312 - Amos U3, 1570144000, P60Y, 0.0406 2021-01-012021-12-31 C000530 BONSACK - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 Other State Tax, VA, 2019 , -1625277 2020-12-31 C000530 Niagara Hydro Project #2466 - Proportion of cost of administering the Federal Water Power Act 2021-01-012021-12-31 C000530 POWELLTON - WV, Distribution, , 46, 7.2, , 2.49,  2021-12-31 C000530 Unrecovered Fuel Cost - VA 2021-12-31 C000530 GLADE - VA, Distribution, , 69, 34.5, , 30,  2021-01-012021-12-31 C000530 0459 GEORGE STREET, LYNBROOK, 1, 1, 1, 1233.6KCM ACSR/TW, 0, 0 2021-01-012021-12-31 C000530 GOMINGO - VA, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 Property Tax, NE, 2019 , 360 2020-12-31 C000530 ferc:OtherElectricUtilityMember 2021-12-31 C000530 IP-Industrial Power Service , 310406 2021-01-012021-12-31 C000530 HILLMAN HIGHWAY - VA, Distribution, , 69, 13.09, , 25,  2021-12-31 C000530 0268 ST ALBANS LOOP, WV, , 3, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Other State Tax, KY, 2019 , -2397 2020-12-31 C000530 Customer Deposits 2020-01-012020-12-31 C000530 SFAS 106 Medicare Subsidy - Amortization period - 1/2013 to 12/2024 2021-12-31 C000530 FIELDALE - VA, Transmission, , 138, 70.5, 36.2, 78,  2021-12-31 C000530 VA Retired Coal Plants - VA SCC Case No. PUR-2020-00015 - Amortization Period: 01/2020 - 05/2025 2021-01-012021-12-31 C000530 163 - Stores Expense Undistributed 2021-01-012021-12-31 C000530 LATROBE - WV, Distribution, , 46, 7.2, , 4.5,  2021-12-31 C000530 332 - Leesville Hydro, 12111000, 0.0219 2021-01-012021-12-31 C000530 Gas Dresden 2021-01-012021-12-31 C000530 ferc:NitrogenOxideMemberferc:CurrentYearMember Wolverine Power Supply Cooperative, Inc. 2021-01-012021-12-31 C000530 Deferred Urea Expense 2021-01-012021-12-31 C000530 Corp Safety & Health, AEPSC , 1812019.45 2021-01-012021-12-31 C000530 CAVE SPRING - VA, Distribution, , 138, 13.09, , 42.4,  2021-01-012021-12-31 C000530 PJM - #AF2-107  , 1051.99ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo Transmission Work 2021-12-31 C000530 0049 BAILEYSVILLE, WV, KANAWHA #2, WV, 1, 0, 0, , 0, 0 2021-01-012021-12-31 C000530 A(6) Other: , Corporate Technology Prog Mgmt 2021-01-012021-12-31 C000530 BANCROFT - WV, Transmission, , 138, 13.09, , 25,  2021-12-31 C000530 BOXWOOD - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 Construction Services, AEPSC , 144023051.01 2021-01-012021-12-31 C000530 PACKSVILLE - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0538 Elk Garden Tap, , 2, 0, 1, 336KCM ACSR, , 2021-01-012021-12-31 C000530 TOTAL HYDRO, 133399000, 2021-01-012021-12-31 C000530 Ceredo Gas 2021-01-012021-12-31 C000530 VA Demand Response Program - Rate Order: VA SCC PUE-2011-0001 2021-12-31 C000530 , IT - EPRI Annual Research Port 2021-01-012021-12-31 C000530 PJM - #AF2-107  , 1051.99 2021-01-012021-12-31 C000530 RIPLEY - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:TransmissionStudiesMember AG2-127 , 1990.52 2021-01-012021-12-31 C000530 CRAB ORCHARD - WV, Distribution, , 46, 12, , 3.75,  2021-01-012021-12-31 C000530 Franchise Tax, TN, 2002 , 2021-01-012021-12-31 C000530 HENRY S.D. - VA, Distribution, , 34.5, 13, , 3.75,  2021-01-012021-12-31 C000530 SISSON - WV, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 3843 BIM, WV, , 1, 11, 0, , 0, 0 2021-01-012021-12-31 C000530 LPS-TOD-PA Large Pow Ser , 37541 , 2483758 2021-01-012021-12-31 C000530 SHIPMAN - VA, Distribution, , 46, 12, , 4.7,  2021-12-31 C000530 DAMERON - WV, Transmission, , 138, 69, 46, 129,  2021-12-31 C000530 MELROSE - VA, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Ds-AP-WVirg-AI Recloser Repl 2021-12-31 C000530 0422 JACKSONS FERRY, VA, PEAK CREEK, VA, 3, 1, 0, 954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 310-311, k, 1 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Unemployment Tax, VA,  , 45848 2021-01-012021-12-31 C000530 KANAWHA CITY - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:SalesAndUseTaxMember 2021-12-31 C000530 RICHLANDS - VA, Transmission, , 138, 69, 13.1, 130,  2021-01-012021-12-31 C000530 KINCAID - WV, Transmission, , 138, 69, 46, 84,  2021-12-31 C000530 Franchise Tax, KY, 2020 , 2020-12-31 C000530 MUDLICK - VA, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 PJM Trans Enhancement Rev Whlsle Various Various FNO 2021-01-012021-12-31 C000530 SKIN FORK - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 AMEAGLE - WV, Distribution, , 46, 7.2, , 2.49,  2021-12-31 C000530 426 - Political Activities 2021-01-012021-12-31 C000530 Purchase New APCO HDQ Building 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/NERC Physical Security 2021-12-31 C000530 SWS-Sanctuary Worship , 99757 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other State Tax, VA, 2020 , 952200 2021-01-012021-12-31 C000530 D/AP/Capital Blanket - APCo 2021-01-012021-12-31 C000530 PJM - #AF2-382  , -167.1ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0095 CARBIDE MAIN, WV, TURNER, WV, 3, 0, 1, 1590 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 APPLE GROVE - WV, Transmission, , 138, 69, 12, 56,  2021-12-31 C000530 FICA 2021 , Federal Insurance Tax, ,  , 15810857 2021-12-31 C000530 0145 ALTAVISTA, VA, REUSENS, VA, 2, 20, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SCOTTSVILLE (AP) - VA, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 GLEN LYN - VA, Transmission, , 138, 13.2, , 18.75,  2021-01-012021-12-31 C000530 A(5) Environment: (Other Than Equipment), 1 Item(s) Under $50,000 2021-01-012021-12-31 C000530 SCOTTSVILLE (AP) - VA, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 HUFF CREEK - WV, Transmission, , 46, 13.09, , 20,  2021-01-012021-12-31 C000530 DISSTON - VA, Distribution, , 69, 4, , 3.13,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember AE2-160 , 2870.35 2021-01-012021-12-31 C000530 Carrying Chgs-Capital Environmental Compliance Csts - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2020-12-31 C000530 PENHOOK - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 0098A FLATWOOD TAP 138KV, , , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 JARROLD - WV, Distribution, , 46, 13.09, , 5,  2021-12-31 C000530 Other State Tax, WV, 2021 , 32682591 2020-12-31 C000530 HARMON BRANCH - WV, Distribution, , 138, 12, , 15,  2021-01-012021-12-31 C000530 ATKINS - VA, Distribution, , 69, 12, , 10.5,  2021-12-31 C000530 GLENWOOD (AP) - VA, Distribution, , 23, 12, , 9.4,  2021-01-012021-12-31 C000530 Income Tax, WV, 2020 , 2021-12-31 C000530 WV Delayed Base Rate Increase - Case No. 16-0179-E-T-PC - Amortization Period: 7/2016 - 6/2018 2020-12-31 C000530 SS-CI-APCo-T GEN PLT 2021-01-012021-12-31 C000530 Other State Tax, OH, 2020 , 320 2020-12-31 C000530 RICHLANDS - VA, Transmission, , 138, 69, 13.09, 78,  2021-12-31 C000530 332 - Marmet Hydro, 1880000, 0.0233 2021-01-012021-12-31 C000530 Inadvertent 2021-01-012021-12-31 C000530 Unemployment Tax, OH,  , 3204 2021-12-31 C000530 ferc:ElectricUtilityMember APCo T Work 2021-01-012021-12-31 C000530 MILTON - WV, Transmission, , 138, 13.09, , 25,  2021-01-012021-12-31 C000530 Other (provide details in footnote):ferc:GasOtherFacilitiesMember 2021-01-012021-12-31 C000530 ATKINS - VA, Distribution, , 138, 34.5, 12, 9.38,  2021-12-31 C000530 SOUTH HILLS - WV, Distribution, , 46, 12, , 22.4,  2021-01-012021-12-31 C000530 MULLENS TOWN - WV, Distribution, , 34.5, 4, , 4.7,  2021-01-012021-12-31 C000530 0464 HUNTINGTON COURT, ROANOKE, 1, 6, 1, 795 ACSR, 0, 0 2021-01-012021-12-31 C000530 Franchise Tax, TN, 2002 , 2020-12-31 C000530 Property Tax, VA, 2020 , 803447 2021-12-31 C000530 Cedar Coal Company 2021-01-012021-12-31 C000530 ferc:LandAndRightsMember Shadwell 69KV Substation, Roanoke County, VA 10.637 acres (7662) 2021-12-31 C000530 WV Vegetation Management Program Costs - Rate Order: WV PSC Case 13-0557-E-P - Rate Order: WV PSC Case 14-1152-E-42T 2021-12-31 C000530 AG1-089 , 1143.12 2021-01-012021-12-31 C000530 0, 0 2021-12-31 C000530 LOUP CREEK - WV, Distribution, , 46, 12, , 3,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AD1-102  , 28501.76 2021-01-012021-12-31 C000530 Property Tax, WV, 2020 , 26656291 2020-12-31 C000530 FRANKLIN - VA, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 Income Tax, TN, 2020 , 20300 2021-01-012021-12-31 C000530 SOURWOOD - WV, Distribution, , 138, 13.09, , 8.4,  2021-01-012021-12-31 C000530 WS-CI-APCo-G PPB 2021-01-012021-12-31 C000530 Environmental Compliance Costs - Rate Orders: VA Code Section 56-582B (vi) VASCCPUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-01-012021-12-31 C000530 SEC File 70-5470, 4-30-74 2021-01-012021-12-31 C000530 RIVERVILLE - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 0358 AXTON, VA, DANVILLE #1-A, VA, 2, 0, 1, 1033.5 ACSR, , 2021-01-012021-12-31 C000530 AMOS 345KV - WV, Transmission, , 345, 138, 34.5, 1350,  2021-12-31 C000530 DUBLIN (AP) - VA, Distribution, , 34.5, 12, , 18.76,  2021-12-31 C000530 ferc:ElectricUtilityMemberferc:ElectricPlantHeldForFutureUseMember 2021-12-31 C000530 Appropriations of Retained Earnings (Acct. 436) 2021-01-012021-12-31 C000530 ferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C000530 GT1B Hot Gas Path 2021-01-012021-12-31 C000530 ferc:IncomeTaxMember 2020-12-31 C000530 T/AP/Danville - Martinsville T 2021-01-012021-12-31 C000530 PLANTATION PIPELINE - VA, Distribution, , 34.5, 7.5, , 4.5,  2021-12-31 C000530 ferc:ElectricUtilityMember Wo 020749999 2021-01-012021-12-31 C000530 0148 CLINCH RIVER, VA, SALTVILLE #1A, VA, 3, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 0ferc:OctoberMember 2021-01-012021-12-31 C000530 0035 STOTESBURY TAP, WV, , 1, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 REUSENS - VA, Transmission, , 138, 69, 13.09, 130,  2021-12-31 C000530 WARD HOLLOW - WV, Transmission, , 46, 13.8, , 40,  2021-01-012021-12-31 C000530 CABELL - WV, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 PEMBERTON - WV, Transmission, , 46, 4, , 5,  2021-12-31 C000530 0, LEESVILLE 2021-12-31 C000530 0420 FRANKS BRANCH, , 1, 5, 1, , 0, 0 2021-01-012021-12-31 C000530 0, LEESVILLE 2021-01-012021-12-31 C000530 0063 BROADFORD, VA, SALTVILLE NO.1A&1B, VA, 3, 0, 2, 556KCM ACSR, , 2021-01-012021-12-31 C000530 PJM - #AE2-166  , -69.89ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 BIM - WV, Transmission, , 138, 69, 46, 84,  2021-12-31 C000530 ferc:CurrentYearMemberferc:SulfurDioxideMember 2021-01-012021-12-31 C000530 RS - Residential Service , 11208849 2021-01-012021-12-31 C000530 Forestry - APCo-T 2021-01-012021-12-31 C000530 Def Equity Income-Securitization 2020-12-31 C000530 John E. Amos Fly Ash Area 3, Putnam Co., WV - approx 132.65 acres of land (0745) 2021-01-012021-12-31 C000530 COAL CREEK - VA, Distribution, , 69, 12, , 10,  2021-12-31 C000530 CLENDENIN - WV, Transmission, , 46, 34.5, 20.9, 25,  2021-12-31 C000530 0414 RIVERVILLE TAP, VA, , 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BALLOU - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 SOUTH PRINCETON - WV, Distribution, , 138, 34.5, , 55,  2021-01-012021-12-31 C000530 0320 EAST LYNCHBURG, VA, JOSHUA FALLS, VA, 1, 1, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 MCGRAWS - WV, Distribution, , 46, 13.09, , 12.5,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:LocalTaxMember 2021-01-012021-12-31 C000530 MORGANS CUT - VA, Transmission, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 PJM - #AE2-166  , -69.89 2021-01-012021-12-31 C000530 Income Tax, MULTI, 2019 , 2021-12-31 C000530 INGLES - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 HANS MEADOW - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Distribution Expenses - Maintenance, I&M , 529657.64 2021-01-012021-12-31 C000530 0 2021-12-31 C000530 0220 KOPPERSTON LOOP, WV, , 3, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HUNTINGTON COURT - VA, Distribution, , 138, 69, 34.5, 175,  2021-01-012021-12-31 C000530 CLINTWOOD - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 395, 3073000, 0.0392 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember WS-CI-APCo-G PPB 2021-12-31 C000530 0145A BOONSBORO LOOP, VA, , 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CARBONDALE - WV, Transmission, , 46, 36.2, , 10.5,  2021-01-012021-12-31 C000530 ferc:TwoYearsMemberferc:SulfurDioxideMember 2020-12-31 C000530 KINCAID - WV, Transmission, , 138, 69, 46, 84,  2021-01-012021-12-31 C000530 FULKS - WV, Distribution, , 34.5, 34.5, 5, 25,  2021-12-31 C000530 SEC File 70-2749, 8.14-50 2021-01-012021-12-31 C000530 Building and Property Leases, AEPSC , 3974794 2021-01-012021-12-31 C000530 VINTON - VA, Distribution, , 138, 13.09, , 25,  2021-12-31 C000530 20211221-5274, 44551, ER17-405 2021-01-012021-12-31 C000530 163 - Stores Expense Undistributedferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C000530 STANLEYTOWN - VA, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 0093 BIG SANDY, WEST HUNGINGTON, WV, 3, 16, 0, , 0, 0 2021-01-012021-12-31 C000530 MCDOWELL - WV, Transmission, , 34.5, 13.2, , 7.5,  2021-12-31 C000530 0308 PAD FORK LOOP, WV, , 1, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WOOLWINE - VA, Distribution, , 69, 34.5, , 25,  2021-01-012021-12-31 C000530 Undistributed earnings/losses and dividends - Central Appalachian Coal 2021-12-31 C000530 PAX BRANCH 138KV - WV, Transmission, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 765, 528, 13.8, 1950,  2021-01-012021-12-31 C000530 MOUNT VIEW - VA, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 FULKS - WV, Distribution, , 34.5, 34.5, 5, 25,  2021-01-012021-12-31 C000530 POPLAR FORK - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 0578 Redeye Extension, , 1, 2021-01-012021-12-31 C000530 PJM Power Factor Credits Rev Whlsl Various Various OS 2021-01-012021-12-31 C000530 TRAMMEL - VA, Transmission, , 69, 12, , 6.25,  2021-01-012021-12-31 C000530 0485 JACKSONS FERRY, WYTHE, 3, 13, 2, 1590KCM ACSR/MA2, 0, 0 2021-01-012021-12-31 C000530 WURNO - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Property Tax, WV, 2020 , 26656291 2021-01-012021-12-31 C000530 PJM - #AG1-092  , -772.37ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 ferc:NitrogenOxideMemberferc:NextTwelveMonthsMember 2020-12-31 C000530 GLENWOOD (AP) - VA, Distribution, , 12, 0.24, , 0.33,  2021-01-012021-12-31 C000530 PINNACLE CREEK - WV, Distribution, , 138, 34.5, , 9.38,  2021-12-31 C000530 PJM - #AE1-212  , 15179.15ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 MONTGOMERY - WV, Distribution, , 46, 12, , 22.4,  2021-01-012021-12-31 C000530 Franchise Tax, TN, 2019 , 2021-12-31 C000530 SLAB FORK - WV, Distribution, , 46, 7.2, , 0.99,  2021-12-31 C000530 VA Major Storm Expense - VA SCC Case No. PUR-2020-00015 2020-12-31 C000530 RIDGEWAY - VA, Transmission, , 138, 34.5, , 25,  2021-12-31 C000530 TRIDENT BROKERAGE SERVICES, LLC, OS, NOTE 1 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Roanoke, VA TOC 2021-12-31 C000530 0361 CLINCH RIVER, VA, SPRING CREEK, VA, 3, 18, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BENT MOUNTAIN - VA, Distribution, , 138, 34, , 10.5,  2021-12-31 C000530 0477 BROAD RUN, WV, THOROFARE CREEK, , 1, 1, , 0, 0 2021-01-012021-12-31 C000530 Income Tax, IL, 2017 , 2021-01-012021-12-31 C000530 AMEAGLE - WV, Distribution, , 46, 7.2, , 2.49,  2021-01-012021-12-31 C000530 OL-Outdoor Lighting , 67736 2021-01-012021-12-31 C000530 POWELLTON - WV, Distribution, , 46, 7.2, , 2.49,  2021-01-012021-12-31 C000530 PJM - #AF2-302  , -167.92ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0053 BAILEYSVILLE, WV, HALES BRANCH, VA, 3, 0, 2, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HILL - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 0077A ADDISON LICK, WV, SPORN, WV, 3, 0, 1, 477KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 NEW CASTLE - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 Property Tax, TN, 2021 , 2021-12-31 C000530 2360104 FICA , Federal Insurance Tax, ,  , 0 2021-01-012021-12-31 C000530 Virginia Broadband Pilot Filing 2021-12-31 C000530 ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 Unemployment Tax, TN,  , 2 2020-12-31 C000530 ferc:ElectricUtilityMember APCo T Work (Supplemental) 2021-01-012021-12-31 C000530 Equity Carrying Chgs-COVID-19 Costs - VA SCC Case No. PUR-2020-00074 2020-12-31 C000530 315 - Amos U3, 37257000, P60Y, 0.0285 2021-01-012021-12-31 C000530 GREENBRIER METERING - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 0216 MULLENS, WV, TAMS MOUNTAIN, WV, 2, 9, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 EAST DANVILLE - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Fuel & Storeroom Services, AEPSC , 11559393.84 2021-01-012021-12-31 C000530 PJM - #AG1-123  , 2484.24 2021-01-012021-12-31 C000530 Corporate Accounting, AEPSC , 3206310.46 2021-01-012021-12-31 C000530 RAVENSWOOD - WV, Distribution, , 69, 13.09, , 25,  2021-12-31 C000530 LAYLAND - WV, Distribution, , 69, 13.09, , 2.5,  2021-12-31 C000530 Note: The Respondent does not have an Executive Committee. 2021-01-012021-12-31 C000530 PJM Trans Owner Serv Rev Whlsle Various Various OLF 2021-01-012021-12-31 C000530 358, 20884000, 0.047 2021-01-012021-12-31 C000530 EAST MONUMENT - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Sales And Use Tax, WV, 2021 , 5210147ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 0216B BRADLEY, WV, TAMS MOUNTAIN, WV, 2, 14, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0222 BRADLEY, WV, KANAWHA #2, WV, 3, 27, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BIM - WV, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 342 Dresden - VA AFUDC, 479000, 0.1951 2021-01-012021-12-31 C000530 Misc Adjustments , 0 , -10959 2021-01-012021-12-31 C000530 Clinch River 2021-12-31 C000530 BLACKWATER - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 RAVENSWOOD - WV, Distribution, , 69, 13.09, , 25,  2021-01-012021-12-31 C000530 AMBLER RIDGE - WV, Distribution, , 138, 138, 34.5, 36,  2021-01-012021-12-31 C000530 Interest Expense Capitalized for Tax 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo D (Floyd-Stuart Area) 2021-12-31 C000530 BIM - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Franchise Tax, KY, 2019 , 2021-01-012021-12-31 C000530 PJM - #AG1-426  , 1374.47ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 Other Taxes, TN, 2021 , 2021-01-012021-12-31 C000530 Property Tax, VA, 2019 , 943 2021-12-31 C000530 VA EE-RAC Over Recovery -Case No. PUR - 2017-00126 2021-12-31 C000530 PINE CREEK - WV, Distribution, , 138, 13.09, , 12.5,  2021-01-012021-12-31 C000530 355, 522241000, 0.0303 2021-01-012021-12-31 C000530 Roanoke, VA TOC 2021-01-012021-12-31 C000530 Virginia Energy Efficiency RAC filing 2021-12-31 C000530 HANCOCK - VA, Transmission, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 AG1-089 , 1143.12ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 TAZEWELL - VA, Transmission, , 34.5, 13, , 6.25,  2021-01-012021-12-31 C000530 Deferred Urea Expense 2020-12-31 C000530 ferc:ElectricUtilityMember GT1A Hot Gas Path 2021-01-012021-12-31 C000530 West Virginia Base Case 2021-01-012021-12-31 C000530 CORNING GLASS (AP) - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 PJM - #AG1-155  , 1677.37ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 Reliability First FAC-003 2021-12-31 C000530 0330 JIM BRANCH, WV, WYOMING, WV, 3, 7, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HUNTINGTON COURT - VA, Distribution, , 69, 34.5, , 75,  2021-12-31 C000530 KENOVA - WV, Transmission, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 MONEL - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 GALLAGHER - WV, Distribution, , 46, 12, , 4.69,  2021-01-012021-12-31 C000530 CORNING GLASS (AP) - VA, Distribution, , 69, 4, , 8.4,  2021-12-31 C000530 WASENA - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 GLEN WHITE - WV, Distribution, , 46, 12, , 6.25,  2021-12-31 C000530 SCHUYLER - VA, Distribution, , 46, 7.2, , 0.83,  2021-01-012021-12-31 C000530 Deferred Revenue - Fiber Optic 2021-01-012021-12-31 C000530 311 - Amos U1&2, 57973000, P61Y, 0.0307 2021-01-012021-12-31 C000530 DOROTHY - WV, Distribution, , 46, 2.3, , 1.5,  2021-12-31 C000530 APCo-D Third Party Work Blkt 2021-01-012021-12-31 C000530 AG2-202 , 1776.39 2021-01-012021-12-31 C000530 DANVILLE - VA, Transmission, , 138, 69, 12, 115,  2021-12-31 C000530 0479 HARMON BRANCH, 138KV EXTENSION, 3, 1, 2, 1033.5 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SKIMMER - VA, Distribution, , 115, 69, , 112,  2021-12-31 C000530 TAZEWELL - VA, Transmission, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 MORGANS CUT - VA, Transmission, , 138, 69, 34.5, 200,  2021-12-31 C000530 FIELDALE - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ELK CREEK - WV, Distribution, , 46, 12, , 3.75,  2021-01-012021-12-31 C000530 HAMPTON - WV, Distribution, , 46, 12, , 3.75,  2021-01-012021-12-31 C000530 Leesville Hydro Project #2210 - Proportion of cost of administering the Federal Water Power Act 2021-01-012021-12-31 C000530 0519 OWENS DRIVE EXT, , 1, 2, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLAYTOR HILLTOP - VA, Transmission, , , 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:ElectricUtilityMember Franchise Tax, TN, 2002 , 2021-01-012021-12-31 C000530 APCO-D Telecom 2021-01-012021-12-31 C000530 368 - VA, 404944000, 0.0305 2021-01-012021-12-31 C000530 FLETCHERS RIDGE - VA, Distribution, , 138, 13.09, , 10.5,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 12, , 12.5,  2021-12-31 C000530 ferc:LandAndRightsMember John E. Amos Fly Ash Area 3, Putnam Co., WV - approx 132.65 acres of land (0745) 2021-12-31 C000530 MINNIX MOUNTAIN - WV, Distribution, , 138, 34, , 25,  2021-01-012021-12-31 C000530 VA E-RAC Deferral AFUDC - Amortization Period: 10/2021 - 09/2022 2021-01-012021-12-31 C000530 Franchise Tax, NC, 2021 , 2100 2020-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 13.09, 34.5, 500,  2021-01-012021-12-31 C000530 SPEEDWAY - WV, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 HUNTINGTON COURT - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 0578 Redeye Extension, , 1, 0, 2, 795KCM ACSR, , 2021-01-012021-12-31 C000530 GARDEN CREEK - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 GLENWOOD (AP) - VA, Distribution, , 23, 12, , 3.75,  2021-01-012021-12-31 C000530 ferc:UnemploymentTaxMember 2020-12-31 C000530 4% 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember DSIT ENTRY - NORMALIZED 2020-12-31 C000530 BECKLEY - WV, Distribution, , 46, 12, , 40,  2021-01-012021-12-31 C000530 Property Taxes West Virginia 2020-12-31 C000530 PJM - #AE2-326  , 2770.71ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 CLINTWOOD - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 0376 DINGESS LOOP, WV, , 1, 0, 0, , 0, 0 2021-01-012021-12-31 C000530 0270 BLUEFIELD, WV, TAZEWELL, VA, 1, 20, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Capital Contributions - Cedar Coal 2021-12-31 C000530 HURLEY - VA, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 ferc:IncomeTaxMember 2021-12-31 C000530 0401 HATFIELD, WV, SPRIGG, WV, 1, 11, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 VA RPS-RAC Over-Recovery 2021-12-31 C000530 ferc:ElectricUtilityMember APCo-D Third Party Work Blkt 2021-12-31 C000530 364 - WV, 436890000, 0.0477 2021-01-012021-12-31 C000530 MORRIS NOVELTY - VA, Distribution, , 34.5, 12, , 3.75,  2021-01-012021-12-31 C000530 Other State Tax, VA, 2021 , 6421600 2020-12-31 C000530 0176 NORTH BRISTOL, VA, WEST KINGSPORT, VA, 3, 6, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Virginia Environmental RAC Filing 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember DSIT Normalized 2020-12-31 C000530 Coal Amos 2021-01-012021-12-31 C000530 0432 MUD FORK LOOP, WV, , 3, 1, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0328 RAGLAND LOOP, WV, , 1, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 332 - London Hydro, 1696000, 0.0197 2021-01-012021-12-31 C000530 Other Taxes, TN, 2020 , 2021-01-012021-12-31 C000530 AG1-311 , 1214.46ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 Other (provide details in footnote): 2021-01-012021-12-31 C000530 345 Dresden Plant, 27938000, 0.0326 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo T (Station) 2021-01-012021-12-31 C000530 COFFEE - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 SGS-Small General Service , 22047 2021-01-012021-12-31 C000530 LCP-Large Capacity Power , 501565 2021-01-012021-12-31 C000530 0351 CLINCH RIVER, VA, NAGEL, TN, 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Contr In Aid of Constr Advance 2020-12-31 C000530 EAST DANVILLE - VA, Transmission, , 230, 138, 34.5, 1500,  2021-12-31 C000530 Franchise Tax, TN, 2018 , 2020-12-31 C000530 Property Tax, LA, 2021 , 1115 2020-12-31 C000530 ELK GARDEN - VA, Distribution, , 138, 36.2, , 30,  2021-12-31 C000530 Undistributed earnings/losses and dividends - Southern Appalachian Coal Company 2020-12-31 C000530 Customer Advance Receipts 2021-12-31 C000530 216, b, 1 2021-01-012021-12-31 C000530 DOROTHY - WV, Distribution, , 46, 2.3, , 1.5,  2021-01-012021-12-31 C000530 373 - WV, 11041000, 0.0817 2021-01-012021-12-31 C000530 336, b, 7 2021-01-012021-12-31 C000530 0359 AXTON, VA, MARTINSVILLE, VA, 3, 11, 1, 966KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0518 TOWN CREEK, SOUTH BLUEFIELD, 1, 1, 1, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0135 AXTON, VA, DANVILLE #2, VA, 1, 17, 0, , 0, 0 2021-01-012021-12-31 C000530 0502 PROGRESS PARK TAP, , 2, 1, 1, 1590KCM ACSR/MA2, 0, 0 2021-01-012021-12-31 C000530 SHARPLES - WV, Distribution, , 46, 12, , 4.69,  2021-12-31 C000530 348 Battery Storage, 5726000, 0.05 2021-01-012021-12-31 C000530 CLEARBROOK - VA, Distribution, , 138, 13.09, , 42.4,  2021-12-31 C000530 PEAKSVIEW - VA, Transmission, , 138, 69, 34.5, 130,  2021-01-012021-12-31 C000530 STONE BRANCH - WV, Distribution, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 ferc:NitrogenOxideMember Chicago Climate Exchange 2021-01-012021-12-31 C000530 Bluefield Office Building 2021-01-012021-12-31 C000530 2021-12-31 C000530 0276 AMOS, WV, HANGING ROCK, H, 3, 25, 1, 954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 FIELDALE - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 367 - VA, 206401000, 0.0183 2021-01-012021-12-31 C000530 ferc:NitrogenOxideMemberferc:TwoYearsMember 2021-01-012021-12-31 C000530 SWITCHBACK - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:ElectricPollutionControlFacilitiesMember 2021-01-012021-12-31 C000530 Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock 2021-01-012021-12-31 C000530 Undistributed earnings/losses and dividends - Southern Appalachian Coal Company 2021-01-012021-12-31 C000530 Investment in Premium on Common Stock 2020-12-31 C000530 SUNSCAPE - VA, Distribution, , 138, 12, , 20,  2021-12-31 C000530 152 - Fuel Stock Undistributed 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember GT1B Hot Gas Path 2021-12-31 C000530 Other License And Fees Tax, WV, 2019 , 2020-12-31 C000530 CLAREMONT - WV, Distribution, , 69, 12, , 8.4,  2021-12-31 C000530 Equity Costs - Capital Reliability - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-01-012021-12-31 C000530 OPOSSUM CREEK - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0338 BLUEFIELD, VA, SOUTH PRINCETON, VA, 1, 6, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, VA, 2020 , 2020-12-31 C000530 0383 WEST SALEM LOOP, VA, , 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Toby L. Thomas, Vice President 2021-01-012021-12-31 C000530 DARRAH - WV, Transmission, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 GLENWOOD (AP) - VA, Distribution, , 12, 0.24, , 0.17,  2021-12-31 C000530 ferc:ElectricUtilityMember T/AP/Roanoke to Kingsport Tele 2021-01-012021-12-31 C000530 0153 NORTH BRISTOL, VA, WEST KINGSPORT, VA, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 GLENWOOD (AP) - VA, Distribution, , 13.2, 0.24, , 0.17,  2021-12-31 C000530 2020 Virginia Triennial Filing 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AG1-240  , 473 2021-01-012021-12-31 C000530 PJM - #AE1-212  , 15179.15 2021-01-012021-12-31 C000530 Income Tax, KY, 2021 , 2021-12-31 C000530 SCOTTSVILLE (AP) - VA, Transmission, , 46, 12, , 5,  2021-12-31 C000530 219, b, 21 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo Distribution Work 2021-12-31 C000530 CURRY - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 NEW HOPE (AP) - WV, Distribution, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 PIPERS GAP - VA, Distribution, , 138, 34, , 30,  2021-01-012021-12-31 C000530 David M. Feinberg, Secretary 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember MT ELG/CCR Compliance 2021-12-31 C000530 Commonwealth of VA , 3781 , 386932 2021-01-012021-12-31 C000530 RIDGEWAY - VA, Transmission, , 138, 13.09, , 9.38,  2021-12-31 C000530 ferc:ElectricUtilityMember Unit 2 Turbine Rotors A & B 2021-12-31 C000530 MT CI SCR CATALYST 2ND LAYERferc:ElectricUtilityMember 2021-12-31 C000530 PIGEON CREEK - WV, Distribution, , 138, 34.5, , 60,  2021-12-31 C000530 AG1-316 , 1915.45 2021-01-012021-12-31 C000530 0101 DEXTER, WV, SPORN CIR B, OH, 1, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 West Virginia Environmental RAC Filing 2021-12-31 C000530 Income Tax, WV, 2017 , 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Amos 1&2 DSI Project 2021-01-012021-12-31 C000530 WV MRBC Surcharge Under Recovery 2021-12-31 C000530 0513 WHITEWOOD EXT, , 1, 1, 2, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0061B RURAL RETREAT, LOOP, WV, 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Other 2021-01-012021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 345, 138, 34.5, 675,  2021-01-012021-12-31 C000530 1,500 shares common stock 2021-12-31 C000530 ferc:NextTwelveMonthsMemberferc:SulfurDioxideMember 2021-01-012021-12-31 C000530 366 - VA, 80848000, 0.0161 2021-01-012021-12-31 C000530 0375 PROGRESS PARK EXT, , 3, 3, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WAYNE - WV, Distribution, , 34.5, 12, , 5,  2021-12-31 C000530 LOCK LANE - WV, Distribution, , 69, 12, , 6.25,  2021-01-012021-12-31 C000530 SOUTH CHRISTIANSBURG - VA, Transmission, , 138, 69, 12, 56,  2021-01-012021-12-31 C000530 MARMET - WV, Distribution, , 46, 12, , 7,  2021-12-31 C000530 ferc:ElectricUtilityMemberferc:OtherProductionPlantMember 2021-01-012021-12-31 C000530 ELM STREET - VA, Distribution, , 34.5, 12, , 20,  2021-12-31 C000530 CAMPBELL AVENUE - VA, Distribution, , 69, 12, , 44.8,  2021-01-012021-12-31 C000530 AMONATE LIGHTS - WV, Distribution, , 34.5, 7.2, , 0.75,  2021-12-31 C000530 CHESTERFIELD AVENUE - WV, Transmission, , 138, 70.5, 46, 90,  2021-12-31 C000530 Income Tax, NOL, 2011 , 2021-12-31 C000530 Other License And Fees Tax, WV, 2021 , 240 2021-01-012021-12-31 C000530 332 - Niagara Hydro, 6734000, 0.0935 2021-01-012021-12-31 C000530 0434 GRASSY CREEK, VA, HALES BRANCH, VA, 3, 6, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 STEAM , , , 2021-01-012021-12-31 C000530 CENTERVILLE - VA, Transmission, , 138, 69, 34.5, 84,  2021-01-012021-12-31 C000530 0003 KYGER CREEK, OH, SPORN, WV, 1, 0, 1, 1272 ACSS, , 2021-01-012021-12-31 C000530 RICH CREEK - WV, Distribution, , 46, 12, , 10.5,  2021-01-012021-12-31 C000530 0526 COMMONWEALTH CROSSING, 138KV EXTENSION, 1, 6, 2, 1033 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Netting of Trading Activities related to Unrealized Gains/Losses on Forward Commitments between Regulated Assets/Liabilities 2020-12-31 C000530 SCOTTSVILLE (AP) - VA, Transmission, , 138, 46, , 40,  2021-01-012021-12-31 C000530 LOUDENDALE - WV, Distribution, , 46, 12, , 10.5,  2021-01-012021-12-31 C000530 0182 JACKSONS FERRY, VA, MCGUIRE, NC, 3, 26, 1, 2049KCM ACAR, 0, 0 2021-01-012021-12-31 C000530 0320 EAST LYNCHBURG, VA, JOSHUA FALLS, VA, 3, 3, 2, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Local Tax, WV, 2021 , 11076357ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 WEST BASSETT - VA, Transmission, , 138, 69, 34.5, 128,  2021-01-012021-12-31 C000530 HANCOCK - VA, Transmission, , 138, 69, 34.5, 128.8,  2021-01-012021-12-31 C000530 RUTH - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 Bus Ops & Perf Assurance, AEPSC , 1817542.29 2021-01-012021-12-31 C000530 Franchise Tax, NC, 2020 , 2020-12-31 C000530 GRAPEVINE - WV, Distribution, , 46, 7.2, , 6.99,  2021-01-012021-12-31 C000530 PROGRESS PARK - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 Niagara - Project #2466 2021-01-012021-12-31 C000530 0192 NORTH BRISTOL, VA, SPRING CREEK, VA, 3, 0, 1, 795 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HUFF CREEK - WV, Transmission, , 46, 13.09, , 20,  2021-12-31 C000530 ferc:ElectricUtilityMemberferc:IntangiblePlantMember 2021-01-012021-12-31 C000530 0478 POLYMER LOOP, WV, , 3, 3, 1, 795 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Sales And Use Tax, OH, 2020 , 2267 2021-12-31 C000530 COTTAGEVILLE - WV, Distribution, , 69, 12, , 6.25,  2021-12-31 C000530 Estimated , 117815 2021-01-012021-12-31 C000530 WEST HUNTINGTON - WV, Transmission, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 VA EE-RAC Under Recovery -Case No. PUR - 2017-00126 2020-12-31 C000530 CLIFFTOP - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 RADFORD - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0322 JOSHUA FALLS, VA, REUSENS A&B, VA, 3, 3, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HUFFMAN - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 Unemployment Tax, OH,  , 3204 2021-01-012021-12-31 C000530 PRINCE - WV, Distribution, , 69, 13.09, , 5.25,  2021-01-012021-12-31 C000530 0110A FALLING BRANCH, LOOP, 2, 1, 1, 556.5 KCM 26/7 AC, 0, 0 2021-01-012021-12-31 C000530 STANLEYTOWN - VA, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 Various Chambers of Commerce 2021-01-012021-12-31 C000530 Wo 020749999 2021-01-012021-12-31 C000530 0003 KYGER CREEK, OH, SPORN, WV, 3, 12, 1, 1414KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Cedar Coal Company 2021-12-31 C000530 Carrying Chgs-Capital Environmental Compliance Csts - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-12-31 C000530 TRAMMEL - VA, Transmission, , 69, 12, , 6.25,  2021-12-31 C000530 STOCKTON - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 Over/Under Recovered Fuel, net 2020-01-012020-12-31 C000530 Property Tax, WV, 2019 , 26137350 2021-12-31 C000530 0, BUCK 2021-01-012021-12-31 C000530 Claytor Hydro Project #739 - Proportion of cost of administering the Federal Water Power Act 2021-12-31 C000530 WALTON PARK - VA, Distribution, , 69, 2.4, , 2,  2021-01-012021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 69, 13.09, , 20,  2021-12-31 C000530 PJM - #AF2-291  , 764.33ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 REUSENS - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Other Taxes, WV, 2020 , 731496 2021-12-31 C000530 APPLE GROVE - WV, Transmission, , 69, 12, , 10.5,  2021-12-31 C000530 MORGANS CUT - VA, Transmission, , 138, 69, 34.5, 84,  2021-12-31 C000530 BRIAR MOUNTAIN - WV, Distribution, , 46, 7.2, , 3,  2021-01-012021-12-31 C000530 RIVERBEND - VA, Distribution, , 69, 12, , 7,  2021-01-012021-12-31 C000530 RIVERBEND - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 SFAS 112 Postemployment Benefits - Rate Order: WV PSC Case 14-1152-E-42T 2020-12-31 C000530 ferc:ElectricUtilityMember Sales And Use Tax, TN, 2019 , 112 2021-01-012021-12-31 C000530 Federal Tax, ,  , 32552283 2020-12-31 C000530 MULLENS, WV, WYOMING, WV, 3, 6, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, TN, 2002 , 2020-12-31 C000530 LAKIN - WV, Transmission, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 0 2021-01-012021-12-31 C000530 Unrealized Loss on Forward Commitments 2020-12-31 C000530 ferc:ElectricUtilityMember SS-CI-APCo-D GEN PLT 2021-01-012021-12-31 C000530 PJM trans enhancement settlement for refund 2021-12-31 C000530 0326 RENSFORD LOOP, WV, KANAWHA, WV, 3, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SEVENTH STREET - VA, Distribution, , 69, 12, , 69.8,  2021-12-31 C000530 HASH RIDGE - WV, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 Claytor Hydro Project #739 - Proportion of cost of administering the Federal Water Power Act 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Ds-Ap-Virg-Ai Recloser Repl 2021-12-31 C000530 JOHNSONS LANE - WV, Distribution, , 34.5, 34.5, 5, 25,  2021-01-012021-12-31 C000530 6,950 shares common stock 2020-12-31 C000530 0, BUCK 2021-12-31 C000530 ferc:ElectricUtilityMember Property Tax, VA, 2020 , 803447 2021-01-012021-12-31 C000530 Capital Contributions Central Coal Company 2020-12-31 C000530 Property Tax, NE, 2019 , 360 2021-01-012021-12-31 C000530 335 - Byllesby Hydro, 1035000, 0.0953 2021-01-012021-12-31 C000530 Central Machine Shop, PSO , 738638 2021-01-012021-12-31 C000530 Book Pension Expense 2021-01-012021-12-31 C000530 BOLT - WV, Transmission, , 138, 69, 46, 129,  2021-12-31 C000530 Infrastructure Ops & Support, AEPSC , 1340289.78 2021-01-012021-12-31 C000530 0005 KANAWHA, WV, MATT FUNK, VA, 3, 1, 1, 2156KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WEST HUNTINGTON - WV, Transmission, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 Income Tax, TN, 2019 , 2021-12-31 C000530 GLEN LYN - VA, Transmission, , 88, 69, 13.1, 84,  2021-12-31 C000530 0168 EAST DANVILLE, VA, SMITH MOUNTAIN, VA, 3, 32, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Property Tax, LA, 2021 , 1115 2021-01-012021-12-31 C000530 Def Equity Income-Securitization 2021-01-012021-12-31 C000530 LGS-TOD - Large General Service-T , 529 2021-01-012021-12-31 C000530 0384 HINTON, WESTVACO, WV, 3, 23, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0353 NAGEL, TN, REEDY CREEK, TN, 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Extra. Loss on Retired Plants 2021-01-012021-12-31 C000530 Other State Tax, VA, 2018 , 0 2021-12-31 C000530 ferc:ElectricUtilityMember AMU2 Air Heater Basket Replace 2021-01-012021-12-31 C000530 CHERRY CREEK - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 TURNER - WV, Transmission, , 138, 70.5, 46, 54,  2021-01-012021-12-31 C000530 Property Tax, MO, 2021 , 14531 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember AF1-049 , 8951.31 2021-01-012021-12-31 C000530 IVY HILL - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA (A), Transmission, , 138, 70.5, 13.09, 78,  2021-01-012021-12-31 C000530 0013 LOGAN, WV, WYOMING #1-A, WV, 3, 12, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PEAKLAND - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 Demand Side Management Under Recovery - Rate Order: WV Public Service Commission - Case No: 10-0261-E-GI - Case No: WV PSC Case 15-0301-E-GI 2021-01-012021-12-31 C000530 Franchise Tax, NC, 2021 , 2100 2021-01-012021-12-31 C000530 Local Tax, WV, 2021 , 11076357 2020-12-31 C000530 LAKE FOREST - VA, Distribution, , 138, 36.2, , 30,  2021-01-012021-12-31 C000530 VA E-RAC CCR Expenses - VA SCC Case No. PUR-2020-00015 - Amortization Period: 10/2021 - 09/2022 2021-12-31 C000530 MULLENS, WV, WYOMING, WV, 1, 17, 0, , 0, 0 2021-01-012021-12-31 C000530 PJM - #AD2-179  , 32903.4 2021-01-012021-12-31 C000530 TOWER 117 - WV, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Appalachian Consumer Rate Relief Funding LLC 2021-01-012021-12-31 C000530 FIELDCREST MILLS - VA, Distribution, , 69, 4, , 20,  2021-12-31 C000530 ABERT - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 OL-Outdoor Lighting , 6654 2021-01-012021-12-31 C000530 PJM - #AE1-121  , 2917.26ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 NORTH CLAYTOR - VA, Transmission, , 138, 69, 34.5, 200,  2021-01-012021-12-31 C000530 APCO-Tranco Line Rebuild-T 2021-01-012021-12-31 C000530 0463 CROOKED CREEK, WV, , 3, 1, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 GS-General Service , 1442 , 159667 2021-01-012021-12-31 C000530 APCo-D Service Restoration Blk 2021-01-012021-12-31 C000530 CAPITALIZED SPARE PARTS, 0373,0379, , 0, 1, , 0, 0 2021-01-012021-12-31 C000530 GILBERT - WV, Distribution, , 46, 12, , 20,  2021-01-012021-12-31 C000530 WURNO - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:NitrogenOxideMemberferc:CurrentYearMember 2021-01-012021-12-31 C000530 KNOTTY POPLAR - VA, Distribution, , 69, 12, , 6.25,  2021-01-012021-12-31 C000530 Aquired Assets 2020-01-012020-12-31 C000530 Income Tax, TN, 2017 , 2021-01-012021-12-31 C000530 0ferc:AprilMember 2021-01-012021-12-31 C000530 Franchise Tax, TN, 2018 , 2021-12-31 C000530 DEARINGTON - VA, Distribution, , 69, 13.09, , 25,  2021-01-012021-12-31 C000530 GLEN LYN - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 AMBLER RIDGE - WV, Distribution, , 138, 36.2, 34.5, 72,  2021-12-31 C000530 BOLT - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 DAMERON - WV, Transmission, , 46, 34.5, , 20,  2021-12-31 C000530 KANAWHA CITY - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Property Tax, WV, 2021 , 82 2021-01-012021-12-31 C000530 331 - London Hydro, 617000, P109Y, 0.0269 2021-01-012021-12-31 C000530 WV Air Quality Permit Fees - Rate Order: WV 15-0722-E-P 2021-12-31 C000530 ferc:ElectricUtilityMember D/AP/Capital Blanket - APCo 2021-01-012021-12-31 C000530 Line cost and expense are, not available by individual, , , , , 1823460928.37, 23654648.88 2021-01-012021-12-31 C000530 COVID-19 Costs - WV General Order: WVPSC 262.4 - VA SCC Case No. PUR-2020-00074 2021-01-012021-12-31 C000530 PJM-Enhancements OS 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 765, , , , REACTOR 2021-01-012021-12-31 C000530 Local Tax, , 2019 , 2021-01-012021-12-31 C000530 Property Tax, VA, 2019 , 943 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Extra. Loss on Retired Plants 2020-12-31 C000530 SHIPMAN - VA, Distribution, , 46, 12, , 4.7,  2021-01-012021-12-31 C000530 APCO Consumer Rate Relief Over Recovery -Rate Order: WV Public Service Commission -Case No. 12-1188-E-PC 2020-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 34.5, 7.2, , 1.5,  2021-12-31 C000530 Agency Fees - Factored A/R 2021-12-31 C000530 372 - VA, 1000, 0.0201 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Roanoke, VA TOC 2021-01-012021-12-31 C000530 Federal Mitigation Deferral - NSR 2021-12-31 C000530 323, b, 185 2021-01-012021-12-31 C000530 0545 Tazewell Bus Tie No 1, , 1, 0, 1, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0245 GILBOA, WV, KANAWHA, WV, 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 EVOLUTION MARKETS FUTURES LLC, OS, NOTE 1 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo T-BlnktProj Under $3M 2021-01-012021-12-31 C000530 MASON CREEK - VA, Distribution, , 69, 12, , 25,  2021-01-012021-12-31 C000530 ALLOY - WV, Distribution, , 46, 13.09, , 9.38,  2021-12-31 C000530 Unrecovered Fuel Cost - WV 2021-12-31 C000530 Unemployment Tax, VA,  , 45848 2021-12-31 C000530 MIKES RUN - WV, Distribution, , 46, 12, , 3.75,  2021-12-31 C000530 ferc:ElectricUtilityMember Sales And Use Tax, TN, 2021 , 1483 2021-01-012021-12-31 C000530 0241 HUFFMAN, VA, WYTHE, VA, 3, 2, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 STATE OF WEST VIRGINIA, STATE OF WEST VIRGINIA, , 0, , , , 2021-01-012021-12-31 C000530 3827 BRADLEY, LAYLAND NO.2B, 1, 1, 1, 1158.4KCM ACSR/TW, 0, 0 2021-01-012021-12-31 C000530 Virginia Generation RAC Filing 2021-01-012021-12-31 C000530 LAKIN - WV, Transmission, , 138, 69, 12, 90,  2021-01-012021-12-31 C000530 EAST DANVILLE - VA, Transmission, , 69, 12, , 8.4,  2021-12-31 C000530 COLLINSVILLE (AP) - VA, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 0306 INEZ, KY, LOGAN, WV, 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SUNDIAL - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 APCO CRR Under Recovery 2021-01-012021-12-31 C000530 PIPERS GAP - VA, Distribution, , 138, 36.2, , 30,  2021-01-012021-12-31 C000530 CAMP GROVE WIND FARM LLC, OS, 2021-01-012021-12-31 C000530 0371 PENHOOK, VA, WESTLAKE, 1, 15, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0054 GARDEN CREEK, VA, HALES BRANCH, VA, 3, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WOLF GLADE - VA, Transmission, , 138, 70.5, 13.09, 78,  2021-12-31 C000530 PJM - #AG1-240  , 473 2021-01-012021-12-31 C000530 PJM - #AG1-089  , 1483.14ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0042 SALTVILLE, VA, TAZEWELL, VA, 1, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Accrued Book Removal Costs 2020-12-31 C000530 ferc:ElectricUtilityMember 10% 2021-12-31 C000530 0364 GRASSY FORK TAP, WV, , 1, 2, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, TN, 2016 , 2021-01-012021-12-31 C000530 Dresden 2021-12-31 C000530 Use of Jointly Owned Facility, WVTCo , 399449 2021-01-012021-12-31 C000530 T/AP/NERC Physical Security 2021-01-012021-12-31 C000530 Unrecovered Fuel Cost - WV 2021-01-012021-12-31 C000530 PRICES FORK - VA, Distribution, , 69, 13.09, , 25,  2021-01-012021-12-31 C000530 Other - SFAS 109ferc:OtherUtilityMember 2021-01-012021-12-31 C000530 Rents Billed in Advance 2021-01-012021-12-31 C000530 MOHAWK RUBBER - VA, Distribution, , 69, 2.4, , 25,  2021-12-31 C000530 ferc:OtherUtilityOrNonutilityMember 0 2021-01-012021-12-31 C000530 0324 CULLODEN, WV, WYOMING, WV, 3, 58, 1, 1351KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Steam Power Generation - Operation, AEPSC , 17954929.82 2021-01-012021-12-31 C000530 MOHAWK RUBBER - VA, Distribution, , 69, 2.4, , 25,  2021-01-012021-12-31 C000530 West Virginia Base Case 2021-12-31 C000530 LAKEVIEW - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 Expenses of Nonutility Operations, I&M , 5016568 2021-01-012021-12-31 C000530 Central Machine Shop, I&M , 2352794 2021-01-012021-12-31 C000530 GRASSY FORK - WV, Distribution, , 138, 34.5, , 20,  2021-01-012021-12-31 C000530 Construction Services, OPCo , 259364 2021-01-012021-12-31 C000530 0016 BAILEYSVILLE, WV, TAZEWELL,  VA, 3, 3, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BOONE - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Other License And Fees Tax, WV, 2019 , 2021-01-012021-12-31 C000530 RICH ACRES - VA, Distribution, , 69, 34.5, , 30,  2021-12-31 C000530 FOREST (AP) - VA, Distribution, , 138, 13.09, , 42.4,  2021-12-31 C000530 ferc:OtherTaxMember 2021-01-012021-12-31 C000530 0076 DARRAH, WV, NORTH PROCTORVILLE, OH, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 1005 CHERRY CREEK, CLIFFTOP, 1, 7, 1, 795 ACSR, 0, 0 2021-01-012021-12-31 C000530 Other State Tax, OH, 2021 , 16687 2020-12-31 C000530 Common Stock 2020-01-012020-12-31 C000530 THORNTON - VA, Distribution, , 138, 34.5, 12, 7.5,  2021-12-31 C000530 T/AP/Charleston to Roanoke Tel 2021-01-012021-12-31 C000530 Income Tax, WV, 2017 , 2021-12-31 C000530 WV Air Quality Permit Fees - Rate Order: WV 15-0722-E-P 2020-12-31 C000530 Kanawha River Plant Demolition Filing 2021-01-012021-12-31 C000530 Transmission Losses 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 69, 13.1, 84,  2021-01-012021-12-31 C000530 CLINTWOOD - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 VA Retired Coal Plants - VA SCC Case No. PUR-2020-00015 - Amortization Period: 01/2020 - 05/2025 2020-12-31 C000530 DSIT ENTRY - NORMALIZED 2021-01-012021-12-31 C000530 , Low Carbon Resource Initiative 2021-01-012021-12-31 C000530 LOCKHART - VA, Distribution, , 138, 13.04, , 20,  2021-12-31 C000530 WV MRBC Surcharge Under Recovery 2021-01-012021-12-31 C000530 0070 CABIN CREEK, WV, TURNER #1 CIR B. WV, 3, 5, 1, 1590KCM ACSR/MA, 0, 0 2021-01-012021-12-31 C000530 0170 LEESVILLE, VA, SMITH MOUNTAIN, VA, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SMYTH - VA, Distribution, , 138, 34.5, , 25,  2021-12-31 C000530 152 - Fuel Stock Undistributedferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C000530 Income Tax, KY, 2021 , 2020-12-31 C000530 M&S Retiring Plants - Rate Order: VA SCC PUE-2014-0026 - Rate Order: WV PSC 14-1151-E-D 2021-12-31 C000530 TOMS FORK - WV, Distribution, , 46, 12, , 4.69,  2021-01-012021-12-31 C000530 UPPER BRANCH - WV, Distribution, , 46, 7.2, , 2.01,  2021-12-31 C000530 VA E-RAC CCR Expenses - VA SCC Case No. PUR-2020-00015 - Amortization Period: 10/2021 - 09/2022 2021-01-012021-12-31 C000530 LOGAN - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 0228A BETH TAP WV, , 1, 1, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:DistributionPlantMember 2021-01-012021-12-31 C000530 0058 GLEN LYN, VA, WYTHE, VA, 3, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SFAS 158 Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans 2021-12-31 C000530 ABINGDON - VA, Transmission, , 138, 34.5, , 50,  2021-12-31 C000530 NAGEL - TN, Transmission, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember D/AP/Distribution Work 2021-12-31 C000530 PUTNAM VILLAGE - WV, Distribution, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 10% 2021-01-012021-12-31 C000530 GALAX - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Carrying Chgs-COVID-19 Costs - VA SCC Case No. PUR-2020-00074 2020-12-31 C000530 Other (Specify)ferc:OtherUtilityMember 2020-12-31 C000530 ferc:TransmissionStudiesMember AG1-091 , 7705.77 2021-01-012021-12-31 C000530 Other - SFAS 109ferc:OtherUtilityMember 2020-12-31 C000530 ferc:ElectricUtilityMemberferc:FederalTaxMember 2021-01-012021-12-31 C000530 Property Tax, TN, 2021 , 2020-12-31 C000530 WEST HUNTINGTON - WV, Transmission, , 138, 13.09, , 9.38,  2021-12-31 C000530 SUN MINE - WV, Distribution, , 46, 12, , 20,  2021-01-012021-12-31 C000530 HUBBARDSTOWN - WV, Distribution, , 138, 34.5, , 20,  2021-01-012021-12-31 C000530 DEPRECIABLE SUM, 15613821000, 2021-01-012021-12-31 C000530 MUD FORK - WV, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 KANAWHA RIVER - WV, Transmission, , 138, 13.09, , 20,  2021-12-31 C000530 FICA 2021 , Federal Insurance Tax, ,  , 15810857 2020-12-31 C000530 0356 PEMBERTON TAP, WV, , 3, 1, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 362 - WV, 277114000, 0.0252 2021-01-012021-12-31 C000530 Property Tax, AR, 2020 , 3078 2020-12-31 C000530 Property Tax, WV, 2020 , 26656291 2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 12, , 9.38,  2021-12-31 C000530 WYTHE - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 WV CCR/ELG AFUDC Deferral - Amortization Period: 09/2021 - 08/2022 2021-01-012021-12-31 C000530 SHEFFIELD (AP) - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 PJM - #AD2-022  , -166.34 2021-01-012021-12-31 C000530 Sales And Use Tax, TN, 2021 , 1483 2020-12-31 C000530 DARRAH - WV, Transmission, , 138, 69, 34.5, 90,  2021-01-012021-12-31 C000530 0, 0 2021-01-012021-12-31 C000530 SEC File 70-1841, 6-18-48 2021-01-012021-12-31 C000530 SOUTH NEAL - WV, Distribution, , 69, 12, , 40,  2021-12-31 C000530 WESTLAKE - VA, Distribution, , 138, 34.5, , 60,  2021-12-31 C000530 ICE TRADE VAULT LLC, OS, 2021-01-012021-12-31 C000530 SOUTHRIDGE - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 AG1-508 , 3377ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 PEAK CREEK - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 VIRGINIA TECH, RQ, 155 2021-01-012021-12-31 C000530 401 - Operation Expense - Nonassociatedferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C000530 ROBINSON - WV, Distribution, , 69, 12, , 10.4,  2021-01-012021-12-31 C000530 Income Tax, IL, 2017 , 2020-12-31 C000530 Property Tax, CO, 2020 , 4861 2021-12-31 C000530 HILLMAN HIGHWAY - VA, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 ferc:FranchiseTaxMember 2021-01-012021-12-31 C000530 Over/Under Recovered Fuel, net 2021-01-012021-12-31 C000530 WYOMING - WV, Transmission, , 765, 138, 13.8, 1250,  2021-12-31 C000530 0141 DANVILLE B CIR, VA, EAST DANVILLE, VA, 3, 0, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0309 EAST LYNCHBURG, VA, OPOSSUM CREEK, VA, 3, 3, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 AG2-568 , 1534.31 2021-01-012021-12-31 C000530 APCO Next Generation Radio Sys 2021-01-012021-12-31 C000530 ROBINSON - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 Nicholas K. Akins, Chairman of the Board and Chief Executive Officer 2021-01-012021-12-31 C000530 Unemployment Tax, OH,  , 3204 2020-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, 20.65, 13.8, ,  2021-01-012021-12-31 C000530 0249 FIELDALE, VA, WEST BASSETT, VA, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PJM - #AF1-323  , -95.21ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 WV ECS Over Recovery 2021-12-31 C000530 Transmission Purchase Expense 2021-01-012021-12-31 C000530 0, MARMET 2021-01-012021-12-31 C000530 NEW CASTLE - VA, Distribution, , 34.5, 12, , 7,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 13.09, , 10.5,  2021-01-012021-12-31 C000530 BENS CREEK - WV, Distribution, , 46, 13.2, , 2.5,  2021-01-012021-12-31 C000530 FLOYD - VA, Transmission, , 138, 69, 34.5, 56,  2021-01-012021-12-31 C000530 0117 HANCOCK, VA, MATT FUNK, VA, 3, 11, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0104 BANCROFT TAP, WV, , 3, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WALNUT AVENUE - VA, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 COVID-19 Costs - WV General Order: WVPSC 262.4 - VA SCC Case No. PUR-2020-00074 2021-12-31 C000530 Virginia Triennial Appeal 2021-12-31 C000530 Property Tax, TN, 2021 , 2021-01-012021-12-31 C000530 0238 AMOS, WV, WEST HUNTINGTON, WV, 1, 0, 0, , 0, 0 2021-01-012021-12-31 C000530 0434 GRASSY CREEK, VA, HALES BRANCH, VA, 1, 2, 0, , 0, 0 2021-01-012021-12-31 C000530 RIVERVILLE - VA, Distribution, , 138, 13.09, , 104,  2021-12-31 C000530 Income Tax, TN, 2018 , 16345 2021-12-31 C000530 BLACKWATER - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA (B), Transmission, , 138, 70.5, 13.09, 78,  2021-01-012021-12-31 C000530 CAMPBELL AVENUE - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 Notes Payable to Associates Companies 2021-01-012021-12-31 C000530 CROSSROADS (AP) - VA, Distribution, , 69, 13.09, , 22.4,  2021-12-31 C000530 GOMINGO - VA, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 Property Tax, VA, 2020 , 803447 2020-12-31 C000530 ferc:ThreeYearsMemberferc:SulfurDioxideMember 2021-12-31 C000530 316 - Amos U3, 29089000, P60Y, 0.032 2021-01-012021-12-31 C000530 Property Tax, VA, 2021 , 25977518 2021-01-012021-12-31 C000530 ferc:SulfurDioxideMember 2021-01-012021-12-31 C000530 Capital Environmental Equity Costs - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-01-012021-12-31 C000530 PJM - #AG1-136  , 1317.78 2021-01-012021-12-31 C000530 FARADAY 138KV - WV, Distribution, , 34.5, 0, 0, 0, AIR CORE REACTOR 2021-12-31 C000530 Netting of Trading Activities related to Unrealized Gains/Losses on Forward Commitments between Regulated Assets/Liabilities 2021-12-31 C000530 DARRAH - WV, Transmission, , 138, 13.09, , 22.4,  2021-12-31 C000530 Customer Service and Informational Expenses, AEPSC , 418594.81 2021-01-012021-12-31 C000530 BECKLEY - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Virginia Environmental RAC Filing 2021-12-31 C000530 FARADAY 138KV - WV, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 CENTRAL MACHINE SHOP - WV, Distribution, , 46, 4, , 3.75,  2021-01-012021-12-31 C000530 Long-Term Issuance Costs 2021-01-012021-12-31 C000530 HANS MEADOW - VA, Distribution, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 BASSETT - VA, Distribution, , 69, 12, , 25,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 345, 34.5, 500,  2021-12-31 C000530 PJM - #AG1-528  , 1640.77 2021-01-012021-12-31 C000530 KANAWHA RIVER - WV, Transmission, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 SS-School Service , 255785 2021-01-012021-12-31 C000530 THOMAS (AP) - VA, Distribution, , 34.5, 7.2, , 3,  2021-12-31 C000530 0396 BONSACK LOOP, VA, , 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Sheridan 69KV Substation, Lincoln County, WV 4.947 acres (2041) 2021-01-012021-12-31 C000530 HOPKINS - WV, Transmission, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 STOTESBURY - WV, Distribution, , 138, 13.09, , 10.5,  2021-01-012021-12-31 C000530 IPP - System Upgrade Credits 2021-12-31 C000530 0460 BRUSH TAVERN, LYNBROOK, 1, 4, 1, 1233.6KCM ACSR/TW, 0, 0 2021-01-012021-12-31 C000530 Carrying Chgs-VA Broadband Pilot - VA SCC Case No. PUR-2019-00145 2021-01-012021-12-31 C000530 BRUSH TAVERN - VA, Distribution, , 138, 34.5, , 60,  2021-12-31 C000530 0436 DAWES LOOP, 138KV, WV, , , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 FAS 109 Deferred Federal Income Tax 2021-12-31 C000530 FREMONT (AP) - VA, Transmission, , 138, 70.5, 13.09, 208,  2021-12-31 C000530 ferc:ElectricUtilityMember Other State Tax, VA, 2021 , 6421600 2021-01-012021-12-31 C000530 SPEEDWAY - WV, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 Distribution Expenses - Maintenance, KgPCo , 933609.78 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Sales And Use Tax, OH, 2021 , 115350 2021-01-012021-12-31 C000530 , , , 0, , , , 2021-01-012021-12-31 C000530 369 - VA, 195859000, 0.0348 2021-01-012021-12-31 C000530 ferc:NitrogenOxideMember 2021-01-012021-12-31 C000530 Unrecovered Fuel Cost - WV 2020-12-31 C000530 SALTVILLE - VA, Transmission, , 138, 34.5, , 20,  2021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AF2-107  , -133.06 2021-01-012021-12-31 C000530 0167A CLINCHFIELD LOOP SITE, , 1, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 314 - Amos U3, 159493000, P60Y, 0.045 2021-01-012021-12-31 C000530 Gas Clinch River 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember D/AP/Distribution Work 2021-01-012021-12-31 C000530 Estimated Barging Bills 2021-12-31 C000530 ferc:NitrogenOxideMemberferc:CurrentYearMember Chicago Climate Exchange 2021-01-012021-12-31 C000530 WYTHE - VA, Transmission, , 138, 34.5, , 35,  2021-12-31 C000530 WHARNCLIFFE - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 Income Tax, IL, 2018 , 2020-12-31 C000530 ferc:ElectricUtilityMemberferc:ExciseTaxMember 2021-01-012021-12-31 C000530 0069 CABIN CREEK, WV, TURNER #1 CIR A, WV, 3, 23, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HARTLAND - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 345, 34.5, 15,  2021-01-012021-12-31 C000530 PJM - #AG1-219  , 1784.34 2021-01-012021-12-31 C000530 0218 AMOS, WV, SPORN, WV, 3, 46, 1, 1563KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ABINGDON - VA, Transmission, , 138, 34.5, , 50,  2021-01-012021-12-31 C000530 0374 PATRIOT CENTRE EXT, , 3, 3, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0350 CLINCH RIVER, VA, NAGEL, TN, 3, 5, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0478 POLYMER LOOP, WV, , 1, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0538 Elk Garden Tap, , 1, 0, 1, 1590KCM ACSR, , 2021-01-012021-12-31 C000530 APCo-T Work 1 2021-01-012021-12-31 C000530 0ferc:DecemberMember 2021-01-012021-12-31 C000530 KENOVA - WV, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0110 CLAYTOR, VA, MATT FUNK, VA, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 EAST HUNTINGTON - WV, Transmission, , 138, 34.5, , 30,  2021-12-31 C000530 MERRITTS CREEK - WV, Distribution, , 138, 36.2, , 30,  2021-01-012021-12-31 C000530 Misc Adjustments , 2021-01-012021-12-31 C000530 BAILEYSVILLE - WV, Transmission, , 46, 12, , 6.25,  2021-12-31 C000530 333 - Buck Hydro, 1937000, 0.0677 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 13.09, 34.5, 15,  2021-01-012021-12-31 C000530 NEW LONDON - VA, Transmission, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 Income Tax, WV, 2020 , 2021-01-012021-12-31 C000530 ESMONT - VA, Distribution, , 46, 12, , 4.69,  2021-01-012021-12-31 C000530 334 - Buck Hydro, 2518000, 0.0771 2021-01-012021-12-31 C000530 SKIMMER - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 AG1-234 , 2118.32 2021-01-012021-12-31 C000530 Property Tax, CO, 2020 , 4861 2020-12-31 C000530 Income Tax, MI, 2017 , 2021-01-012021-12-31 C000530 188 - Research & Developmentferc:DirectPayrollDistributionMember 2021-01-012021-12-31 C000530 0023 MINNIX MOUNTAIN LOOP, , 3, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PJM - #AD2-178  , -31.25 2021-01-012021-12-31 C000530 Property Tax, WV, 2021 , 82 2021-12-31 C000530 BENT MOUNTAIN - VA, Distribution, , 138, 13.09, , 8.4,  2021-12-31 C000530 Income Tax, TN, 2002 , 2021-01-012021-12-31 C000530 PRINCETON - WV, Distribution, , 34.5, 12, , 20,  2021-01-012021-12-31 C000530 MONTEREY - VA, Distribution, , 69, 12, , 10.5,  2021-12-31 C000530 0422 JACKSONS FERRY, VA, PEAK CREEK, VA, 1, 13, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 JOHNSONS LANE - WV, Distribution, , 34.5, 34.5, 5, 25,  2021-12-31 C000530 0075 SOUTH POINT, OH, SPORN, WV, 1, 1, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 345, 34.5, 500,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo Transmission Work 2021-01-012021-12-31 C000530 LAKIN - WV, Transmission, , 138, 69, 12, 90,  2021-12-31 C000530 Investment in Subsidiary AOCI 2020-12-31 C000530 KUMIS - VA, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 POUND - VA, Distribution, , 69, 34.5, , 25,  2021-12-31 C000530 Investment in Subsidiary AOCI 2021-12-31 C000530 ferc:ElectricUtilityMember APCo D Work (Supplemental) 2021-12-31 C000530 VINTON - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 0377 SPORN, CLINE ENERGY EXTENSION, 1, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Excise Tax, , 2021 , 16433 2021-01-012021-12-31 C000530 0020 GLEN LYN, VA, SOUTH PRINCETON, WV, 3, 13, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 APCO: 2020 - 2022 RBB Grayson 2021-01-012021-12-31 C000530 Other (provide details in footnote): 2020-01-012020-12-31 C000530 0355 NAGEL, TN, WEST KINGSPORT, TN, 3, 0, 1, 556KCM, 0, 0 2021-01-012021-12-31 C000530 CATAWBA - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 Ds-Ap-Virg-Ai Recloser Repl 2021-01-012021-12-31 C000530 ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2021-12-31 C000530 DALEWOOD - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 AM CCR/ELG Compliance 2021-01-012021-12-31 C000530 BRADLEY - WV, Transmission, , 46, 12, , 8.4,  2021-12-31 C000530 SEVENTH STREET - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 NAGEL - TN, Transmission, , 500, 230, 13.8, 750,  2021-01-012021-12-31 C000530 SOUTH CHRISTIANSBURG - VA, Transmission, , 138, 69, 12, 56,  2021-12-31 C000530 ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2020-12-31 C000530 0029 CABIN CREEK, WV, KANAWHA #2, WV, 3, 3, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0, WINFIELD 2021-12-31 C000530 KANAWHA RIVER - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 0081 RAVENSWOOD, WV, SPORN #2, WV, 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PEYTONA - WV, Distribution, , 46, 13.09, , 10.5,  2021-01-012021-12-31 C000530 MIDKIFF - WV, Distribution, , 138, 34.5, , 20,  2021-12-31 C000530 VA Demand Response Program - Rate Order: VA SCC PUE-2011-0001 2020-12-31 C000530 DEARINGTON - VA, Distribution, , 69, 13.09, , 25,  2021-12-31 C000530 CAMPBELL AVENUE - VA, Distribution, , 69, 34.5, , 30,  2021-01-012021-12-31 C000530 0243 BOLT TAP, WV, , 1, 6, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 312 - Little Broad Mtn, 50334000, P0Y, 0.0371 2021-01-012021-12-31 C000530 ferc:UnemploymentTaxMember 2021-01-012021-12-31 C000530 CARSWELL - WV, Transmission, , 138, 88, 7.98, 60,  2021-12-31 C000530 LEBANON - VA, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Wo 020749999 2021-12-31 C000530 PERKINS PARK - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 Sales And Use Tax, VA, 2020 , 242451 2021-01-012021-12-31 C000530 Property Taxes - Capital Leases West Virginia 2021-12-31 C000530 0294 NORTH BECKLEY LOOP, WV, , 3, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CABIN CREEK 46KV - WV, Transmission, , 138, 46.2, , 75,  2021-12-31 C000530 CEREDO - WV, Distribution, , 34.5, 4, , 6.25,  2021-12-31 C000530 PJM trans enhancement settlement for refund 2021-01-012021-12-31 C000530 0224 BRADLEY CIR-B, WV, GLEN LYN-HINTON, 3, 4, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SFAS 109 Deferred Federal Income Tax 2021-01-012021-12-31 C000530 CATAWBA - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 VA E-RAC CCR Expenses - VA SCC Case No. PUR-2020-00015 - Amortization Period: 10/2021 - 09/2022 2020-12-31 C000530 ROANOKE ELECTRIC STEEL - VA, Distribution, , 138, 34.5, , 16.67,  2021-01-012021-12-31 C000530 0464 HUNTINGTON COURT, ROANOKE, 1, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0096 CARBIDE #8, WV, CHEMICAL-TURNER A, WV, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BROOKVILLE - VA, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 MATT FUNK 345KV - VA, Transmission, , 345, 138, 34.5, 675,  2021-12-31 C000530 TAZEWELL - VA, Transmission, , 34.5, 12, , 6.25,  2021-12-31 C000530 PARK HILL - WV, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 DARRAH - WV, Transmission, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 MEADOW BRIDGE - WV, Distribution, , 69, 34.5, , 8.4,  2021-12-31 C000530 0167 CLINCH RIVER, VA, GARDEN CREEK, VA, 3, 2, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 311 - Amos U3, 117018000, P60Y, 0.0297 2021-01-012021-12-31 C000530 TAZEWELL - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 PJM - #AE1-250  , 2171.23 2021-01-012021-12-31 C000530 AG2-168 , 2068.78 2021-01-012021-12-31 C000530 SEC File 70-1770, 4-30-48 2021-01-012021-12-31 C000530 0ferc:MayMember 2021-01-012021-12-31 C000530 MONROE (AP) - VA, Distribution, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 WV Manufacturing , 506155 2021-01-012021-12-31 C000530 CAMPBELL AVENUE - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 SPRIGG - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 BELVA - WV, Transmission, , 138, 46, , 30,  2021-01-012021-12-31 C000530 FARADAY 138KV - WV, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 FIELDALE - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 SHABDUE - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 LSE Formula Rate Defer-Dep 2021-01-012021-12-31 C000530 2023 Virginia Triennial Filing 2021-01-012021-12-31 C000530 TRI-STATE - WV, Transmission, , 345, 137.5, 13.8, 270,  2021-01-012021-12-31 C000530 HALES BRANCH - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 U3 IP ROTOR & CYLINDER REFURBI 2021-01-012021-12-31 C000530 BAILEYSVILLE - WV, Transmission, , 138, 46, , 90,  2021-12-31 C000530 AG2-187 , 1732.23ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 CAMPBELL AVENUE - VA, Distribution, , 69, 34.5, , 30,  2021-12-31 C000530 LOCK LANE - WV, Distribution, , 69, 12, , 6.25,  2021-12-31 C000530 HANSONVILLE - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 FRIES - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 PROGRESS PARK - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 Oil Amos 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:SalesAndUseTaxMember 2021-01-012021-12-31 C000530 0ferc:Quarter2Member 2021-01-012021-12-31 C000530 RUTH - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 Ceredo 2021-01-012021-12-31 C000530 BELVA - WV, Transmission, , 138, 46, , 30,  2021-12-31 C000530 3843 BIM, WV, , 3, 0, 1, , 0, 0 2021-01-012021-12-31 C000530 NEW HOPE (AP) - WV, Distribution, , 138, 34.5, , 25,  2021-12-31 C000530 TACKETT CREEK - WV, Distribution, , 138, 13.09, , 25,  2021-12-31 C000530 ferc:OtherUtilityMember 2020-12-31 C000530 TULTEX - VA, Distribution, , 34.5, 7.5, , 2.5,  2021-01-012021-12-31 C000530 PJM - #AF2-106  , -375.09 2021-01-012021-12-31 C000530 Property Tax, AR, 2020 , 3078 2021-12-31 C000530 MINK SHOALS - WV, Distribution, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 SOUTHRIDGE - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 MILTON - WV, Transmission, , 69, 36.2, , 30,  2021-01-012021-12-31 C000530 AG1-528 , 1596.64 2021-01-012021-12-31 C000530 INGLES - VA, Distribution, , 69, 13.09, , 20,  2021-12-31 C000530 MERRITTS CREEK - WV, Distribution, , 138, 36.2, , 30,  2021-12-31 C000530 APPLE GROVE - WV, Transmission, , 138, 69, 12, 56,  2021-01-012021-12-31 C000530 HINTON (AP) - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 HOPKINS - WV, Transmission, , 138, 69, 46, 56,  2021-01-012021-12-31 C000530 320, b, 25 2021-01-012021-12-31 C000530 Urea, KPCo , 1367952 2021-01-012021-12-31 C000530 VA EE-RAC Over Recovery -Case No. PUR - 2017-00126 2020-12-31 C000530 LOGAN - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 POPLAR FORK - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 M&S Retiring Plants - Rate Order: VA SCC PUE-2014-0026 - Rate Order: WV PSC 14-1151-E-D 2021-01-012021-12-31 C000530 PJM - #AF1-323  , -104.14 2021-01-012021-12-31 C000530 CLAYPOOL HILL - VA, Distribution, , 138, 13.09, , 40,  2021-01-012021-12-31 C000530 MONROE (AP) - VA, Distribution, , 69, 13.09, , 20,  2021-12-31 C000530 CLH 4 Tailrace Disolved Oxygen 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo-D Small Cap Adds Blkt 2021-12-31 C000530 354, 514149000, 0.0167 2021-01-012021-12-31 C000530 Ds-AP-WVirg-AI Recloser Repl 2021-01-012021-12-31 C000530 PJM - #AE2-166  , 7937.25 2021-01-012021-12-31 C000530 Other State Tax, VA, 2017 , 2021-12-31 C000530 BLUE RIDGE - VA, Distribution, , 12, 4, , 0.3,  2021-12-31 C000530 Other - SFAS 109ferc:OtherUtilityMember 2021-12-31 C000530 Other License And Fees Tax, WV, 2021 , 240 2021-12-31 C000530 Equity Costs - Capital Reliability - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-12-31 C000530 Other State Tax, FIN48,  , 2021-01-012021-12-31 C000530 KOPPERSTON - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 TECH DRIVE - VA, Distribution, , 138, 12, , 20,  2021-01-012021-12-31 C000530 AG1-509 , 2774.91 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember GT1B Hot Gas Path 2021-01-012021-12-31 C000530 Distribution Expenses - Maintenance, WPCo 2021-01-012021-12-31 C000530 ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 GLENWOOD (AP) - VA, Distribution, , 23, 12, , 9.4,  2021-12-31 C000530 PEAK CREEK - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 PJM - #AG1-155  , 1677.37 2021-01-012021-12-31 C000530 397.12, 41000, 0.0494 2021-01-012021-12-31 C000530 VICKER - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 331 - Byllesby Hydro, 1216000, P112Y, 0.0983 2021-01-012021-12-31 C000530 BIG BRANCH - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 Capital Contributions Central Coal Company 2021-12-31 C000530 PJM AC1-122 & 123 ,ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 GRUNDY - VA, Transmission, , 69, 34.5, , 25,  2021-12-31 C000530 ferc:ElectricPollutionControlFacilitiesMember 2021-12-31 C000530 LOGAN - WV, Transmission, , 138, 13.09, , 22.4,  2021-12-31 C000530 GS-TOD-PA-Gen Ser TOD -PA , 2542 , 231056 2021-01-012021-12-31 C000530 Sales And Use Tax, WV, 2021 , 5210147 2020-12-31 C000530 PJM - #AE2-140  , -368.74 2021-01-012021-12-31 C000530 Virginia Fuel Filing 2021-01-012021-12-31 C000530 T/AP/Sheridan Trans CI 2021-01-012021-12-31 C000530 WYTHE - VA, Transmission, , 138, 34, , 25,  2021-12-31 C000530 HOPKINS - WV, Transmission, , 138, 34.5, , 20,  2021-12-31 C000530 BELVA - WV, Transmission, , 138, 34.5, , 9.38,  2021-01-012021-12-31 C000530 BALLOU - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0465 SUNSCAPE, , 1, 1, 2, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Property Tax, MO, 2021 , 14531 2021-12-31 C000530 0409 LOONEY CREEK TAP, VA, , 3, 10, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA (B), Transmission, , 138, 70.5, 13.09, 78,  2021-12-31 C000530 KANAWHA CITY - WV, Distribution, , 46, 12, , 22.4,  2021-01-012021-12-31 C000530 EAST DANVILLE - VA, Transmission, , 230, 138, 34.5, 1500,  2021-01-012021-12-31 C000530 Income Tax, VA, 2020 , 2021-12-31 C000530 Miscellaneous 2020-12-31 C000530 Property Tax, WV, 2021 , 82 2021-01-012021-12-31 C000530 PEAK CREEK - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 361 - WV, 26460000, 0.019 2021-01-012021-12-31 C000530 331 - Marmet Hydro, 946000, P109Y, 0.0201 2021-01-012021-12-31 C000530 20210525-5243, 44341, ER17-405 2021-01-012021-12-31 C000530 332, 32125000, 0.0154 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/CrningGls-Rdgewy69kv:Relo 2021-01-012021-12-31 C000530 WEST HUNTINGTON - WV, Transmission, , 138, 13.09, , 9.38,  2021-01-012021-12-31 C000530 Income Tax, IL, 2021 , 2021-01-012021-12-31 C000530 Property Tax, MO, 2021 , 14531 2020-12-31 C000530 WEST HUNTINGTON - WV, Transmission, , 138, 69, 34.5, 130,  2021-12-31 C000530 ORTIN - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 SPRIGG - WV, Transmission, , 138, 69, 46, 84,  2021-12-31 C000530 0311 OPOSSUM CREEK, VA, REUSENS, VA, 1, 0, 2, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Property Tax, WV, 2021 , 82 2020-12-31 C000530 0187 BROADFORD, VA, JACKSONS FERRY, VA, 3, 954KCM ACSR 2021-01-012021-12-31 C000530 HURRICANE - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 MILBURN - WV, Distribution, , 46, 7.2, , 1.5,  2021-12-31 C000530 SOUTH NEAL - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 GALAX - VA, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 Netting of Trading Activities related to Unrealized Gains/Losses on Forward Commitments between Regulated Assets/Liabilities 2021-01-012021-12-31 C000530 SOUTH CHARLESTON - WV, Distribution, , 46, 12, , 22.4,  2021-01-012021-12-31 C000530 WV Deferred Storm Expense 2021-12-31 C000530 0249 FIELDALE, VA, WEST BASSETT, VA, 1, 6, 0, , 0, 0 2021-01-012021-12-31 C000530 0393 RONCEVERTE LOOP, WV, , 3, 0, 1, 4/0 ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo-T Work 2021-12-31 C000530 GRAPEVINE - WV, Distribution, , 46, 7.2, , 6.99,  2021-12-31 C000530 MAMMOTH - WV, Distribution, , 46, 12, , 3.75,  2021-12-31 C000530 Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock 2021-01-012021-12-31 C000530 AXTON - VA, Transmission, , 138, 0, 0, 0, AIR CORE REACTOR 2021-12-31 C000530 Income Tax, KY, 2021 , 2021-01-012021-12-31 C000530 0212 PINNACLE CREEK LOOP, W, , 3, 3, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0400 CANE RIVER, TN CIR-A, NAGEL, TN, 3, 46, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SCARBRO - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Accrued Book ARO Expenses 2021-12-31 C000530 Factored AR, AEP Credit Inc. , 2406043.35 2021-01-012021-12-31 C000530 FREMONT (AP) - VA, Transmission, , 138, 70.5, 13.09, 208,  2021-01-012021-12-31 C000530 Other Accounts (Specify, details in footnote):ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 SOUTH LYNCHBURG - VA, Transmission, , 138, 13.09, , 40,  2021-01-012021-12-31 C000530 TAZEWELL - VA, Transmission, , 34.5, 13, , 6.25,  2021-12-31 C000530 Construction Services, KgPCo , 924571 2021-01-012021-12-31 C000530 SALTVILLE - VA, Transmission, , 138, 13.09, , 10.5,  2021-12-31 C000530 Distribution Expenses - Maintenance, OPCo , 1749030.18 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo T-BlnktProj Under $3M 2021-12-31 C000530 ferc:NitrogenOxideMember 2021-12-31 C000530 Agency Fees - Factored A/R 2021-01-012021-12-31 C000530 BRIDGE - WV, Distribution, , 69, 13.09, , 45,  2021-01-012021-12-31 C000530 JIM BRANCH - WV, Transmission, , 138, 69, 46, 128.8,  2021-01-012021-12-31 C000530 WV Deferred Rate Case Expenses - WVPSC Case #18-0646-E-42T - Amortization Period: 03/2019 - 02/2022 2021-01-012021-12-31 C000530 0061 ATKINS, VA, BROADFORD CIR B, VA, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Other State Tax, FIN48,  , 2021-12-31 C000530 Unamortized Credit Line Fees Amortization through June 2022 2021-12-31 C000530 MORRIS NOVELTY - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Other State Tax, WV, 2021 , 32682591 2021-01-012021-12-31 C000530 Property Tax, TN, 2021 ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 HUNTINGTON COURT - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 2020-01-012020-12-31 C000530 FAS 109 Deferred Federal Income Tax 2021-01-012021-12-31 C000530 AG1-219 , 1879.94 2021-01-012021-12-31 C000530 Unemployment Tax, TN,  , 2 2021-12-31 C000530 Estimated , 0 , 0 2021-01-012021-12-31 C000530 MATT FUNK 345KV - VA, Transmission, , 345, 138, 13.1, 672,  2021-01-012021-12-31 C000530 0024 SPEEDWAY TAP, WV, , 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 EAST DANVILLE - VA, Transmission, , 138, 69.5, 13.09, 60,  2021-12-31 C000530 0173 ALTAVISTA, VA, LEESVILLE, VA, 1, 3, 0, , 0, 0 2021-01-012021-12-31 C000530 ferc:LandAndRightsMember John E. Amos Fly Ash Area 3, Putnam Co., WV - approx 132.65 acres of land (0745) 2021-01-012021-12-31 C000530 CANDLERS MOUNTAIN - VA, Distribution, , 138, 13.09, , 22.4,  2021-01-012021-12-31 C000530 FULKS - WV, Distribution, , 34.5, 13.09, , 9.38,  2021-12-31 C000530 PJM Trans Enhancement Rev Various Various FNO 2021-01-012021-12-31 C000530 0429 MIDKIFF, WV, TRI STATE, WV, 1, 26, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0238 PARK HILL TAP, WV, , 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SFAS 106 Medicare Subsidy - Amortization period - 1/2013 to 12/2024 2021-01-012021-12-31 C000530 ABINGDON - VA, Transmission, , 138, 70.5, 13.09, 90,  2021-01-012021-12-31 C000530 0380 FALLING BRANCH, MERRIMAC, 1, 1, 1, 1033 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PERKINS PARK - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 Transmission Expenses - Operation, AEPSC , 21375898.03 2021-01-012021-12-31 C000530 0004 MUSKINGUM, WV, SPORN, WV, 1, 2, 2, 959.6 KCM ACSS, 0, 0 2021-01-012021-12-31 C000530 BLUEFIELD AVENUE - WV, Distribution, , 138, 13.09, , 44.8,  2021-01-012021-12-31 C000530 2020 Virginia Triennial Filing 2021-12-31 C000530 AMOS 765KV - WV, Transmission, , 138, 69, 46, 130,  2021-12-31 C000530 BEARWALLOW - VA, Transmission, , 138, 70.5, 13.09, 54,  2021-12-31 C000530 HUGHESTON - WV, Distribution, , 46, 2.4, , 2.5,  2021-12-31 C000530 CENTRAL AVENUE (AP) - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 TURNER - WV, Transmission, , 69, 35.4, 13.8, 30,  2021-12-31 C000530 WELLS FARGO SECURITIES, LLC, OS, NOTE 1 2021-01-012021-12-31 C000530 SPRIGG - WV, Transmission, , 138, 13.2, 12, 9.38,  2021-01-012021-12-31 C000530 TULTEX - VA, Distribution, , 34.5, 7.2, , 5,  2021-12-31 C000530 0015 BERWIND, FARADAY, , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 KANAWHA RIVER - WV, Transmission, , 345, 138, 13.8, ,  2021-12-31 C000530 PROGRESS PARK - VA, Distribution, , 138, 36.2, , 30,  2021-12-31 C000530 Deferred Gain - Fiber Optic Leases 2021-01-012021-12-31 C000530 0225 SOUTH BUFFALO, WV, SPORN CIR B WV, 3, 36, 1, 1351KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 MULLENS TOWN - WV, Distribution, , 34.5, 4, , 4.7,  2021-12-31 C000530 SGS-Small Gen. Service , 10 2021-01-012021-12-31 C000530 PINE CREEK - WV, Distribution, , 138, 13.09, , 12.5,  2021-12-31 C000530 WV Delayed Base Rate Increase - Case No. 16-0179-E-T-PC - Amortization Period: 7/2016 - 6/2018 2021-01-012021-12-31 C000530 Dresden 2021-01-012021-12-31 C000530 KENOVA - WV, Transmission, , 138, 34.5, , 30,  2021-12-31 C000530 0581 Museville Extension, , 1, 0, 2, 1272 ACSS, , 2021-01-012021-12-31 C000530 Congestion 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember 7% 2021-01-012021-12-31 C000530 VA EE-RAC Over Recovery -Case No. PUR - 2017-00126 2021-01-012021-12-31 C000530 ferc:LandAndRightsMember Items under $250,000 2021-12-31 C000530 NEECE CREEK - VA, Distribution, , 69, 12, , 8.4,  2021-12-31 C000530 CIAC 2021-01-012021-12-31 C000530 332 - Buck Hydro, 7896000, 0.0932 2021-01-012021-12-31 C000530 0226 AMOS, WV, CHEMICAL #1 B, WV, 3, 6, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 TONEY FORK - WV, Distribution, , 46, 12, , 8.4,  2021-12-31 C000530 RIVERBEND - VA, Distribution, , 69, 12, , 9.38,  2021-12-31 C000530 Capital Environmental Equity Costs - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2020-12-31 C000530 CITIGROUP ENERGY INC., OS, NOTE 1 2021-01-012021-12-31 C000530 Property Tax, TN, 2020 , 1392679 2020-12-31 C000530 0311 OPOSSUM CREEK, VA, REUSENS, VA, 3, 9, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 RIDGEWAY - VA, Transmission, , 138, , , , REACTOR 2021-12-31 C000530 EAST LYNCHBURG - VA, Transmission, , 138, 69, 34.5, 196,  2021-12-31 C000530 Unemployment Tax, ,  , 76346 2020-12-31 C000530 0515 FARADAY, TAZEWELL, 2, 7, 1, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO-D Telecom 2021-12-31 C000530 ferc:ElectricUtilityMember U3 IP ROTOR & CYLINDER REFURBI 2021-12-31 C000530 CLEARBROOK - VA, Distribution, , 138, 13.09, , 42.4,  2021-01-012021-12-31 C000530 Franchise Tax, TN, 2017 , 2021-01-012021-12-31 C000530 DEARINGTON - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 FRANKLIN - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 HANSONVILLE - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 HURRICANE - WV, Distribution, , 69, 12, , 25,  2021-12-31 C000530 ferc:ElectricUtilityMember APCO Trans Pre Eng Parent 2021-12-31 C000530 GUTHRIE - WV, Distribution, , 46, 34.5, , 25,  2021-01-012021-12-31 C000530 KENOVA - WV, Transmission, , 138, 69, 46, 150,  2021-12-31 C000530 365 - WV, 571354000, 0.0338 2021-01-012021-12-31 C000530 GLEN LYN - VA, Transmission, , 88, 69, 13.1, 84,  2021-01-012021-12-31 C000530 HARMON BRANCH - WV, Distribution, , 138, 12, , 15,  2021-12-31 C000530 CLOVERDALE 765KV - VA (G), Transmission, , 138, 70.5, 36.2, 78,  2021-12-31 C000530 ferc:ElectricUtilityMember CIS-Common Deployment-APC D 2021-01-012021-12-31 C000530 396, 133000, 0.0184 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO Trans Pre Eng Parent 2021-01-012021-12-31 C000530 Income Tax, KY, 2020 , 2021-12-31 C000530 0248 CLAYTOR, VA, FIELDALE, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SMYTH - VA, Distribution, , 138, 36.2, , 30,  2021-01-012021-12-31 C000530 Legal GC/Administration, AEPSC , 8423788.96 2021-01-012021-12-31 C000530 STUART - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 2360104 FICA , Federal Insurance Tax, ,  , 0 2020-12-31 C000530 0270 BLUEFIELD, WV, TAZEWELL, VA, 2, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 APCo T Work (Supplemental) 2021-01-012021-12-31 C000530 Environmental Services, AEPSC , 836884.86 2021-01-012021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, 20.65, 13.8, ,  2021-12-31 C000530 0428 SHARPLES TAP 138KV, , 1, 7, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Teays Valley SC Land Purchase 2021-01-012021-12-31 C000530 Property Taxes - Capital Leases West Virginia 2021-01-012021-12-31 C000530 MULLENS - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 Sales And Use Tax, WV, 2020 , 661831 2021-12-31 C000530 AG2-127 , 1990.52 2021-01-012021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 345, 137.5, 13.14, 448,  2021-01-012021-12-31 C000530 CABIN CREEK 46KV - WV, Transmission, , 138, 46, , 75,  2021-12-31 C000530 0093 BIG SANDY, WEST HUNTINGTON, WV, 3, 3, 1, 1351KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 VA T-RAC Costs - VA SCC Case No. PUE-2009-00031 2021-01-012021-12-31 C000530 BLUEFIELD AVENUE - WV, Distribution, , 138, 13.09, , 44.8,  2021-12-31 C000530 Other (Specify)ferc:OtherUtilityMember 2021-01-012021-12-31 C000530 SUNDIAL - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:LandAndRightsMember Shadwell 69KV Substation, Roanoke County, VA 10.637 acres (7662) 2021-01-012021-12-31 C000530 BIG BRANCH - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Franchise Tax, NC, 2019 , 2021-01-012021-12-31 C000530 GRUNDY - VA, Transmission, , 69, 12, , 10.5,  2021-12-31 C000530 GARDEN CREEK - VA, Transmission, , 138, 69.5, 13.09, 84,  2021-12-31 C000530 ROANOKE ELECTRIC STEEL - VA, Distribution, , 138, 34.5, , 197,  2021-01-012021-12-31 C000530 RONDA - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 Other Accounts (Specify, details in footnote): 2021-01-012021-12-31 C000530 0569 HINTON, WEST VACO (VA), 3, 0, 1, 336KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 FOWLER RIDGE III WIND FARM LLC, OS, 2021-01-012021-12-31 C000530 BLAINE - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0ferc:SeptemberMember 2021-01-012021-12-31 C000530 RURAL RETREAT - VA, Distribution, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 MULLENS - WV, Transmission, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/Roanoke to Kingsport Tele 2021-12-31 C000530 CLINTWOOD - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 2020 PJM Transmission True-Up - VA SCC Case No. PUR-2020-00015 2020-12-31 C000530 ferc:SalesAndUseTaxMember 2021-01-012021-12-31 C000530 333 - Claytor Hydro, 4184000, 0.0308 2021-01-012021-12-31 C000530 Other State Tax, WV, 2021 , 32682591 2021-12-31 C000530 TOTAL STEAM, 5542650000, , 2021-01-012021-12-31 C000530 TAZEWELL - VA, Transmission, , 138, 34.5, , 30,  2021-12-31 C000530 Income Tax, WV, 2021 , 2021-01-012021-12-31 C000530 RIVERMONT - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 0063 ATKINS, VA, WYTHE CIR A, VA, 3, 22, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 , , ,  , 2020-12-31 C000530 IPP - System Upgrade Credits 2020-12-31 C000530 SMYTH - VA, Distribution, , 138, 34.5, , 25,  2021-01-012021-12-31 C000530 KENOVA - WV, Transmission, , 34.5, 13.09, , 9.38,  2021-12-31 C000530 MGS-PA-Med Gen Ser - PA , 151557 , 14712784 2021-01-012021-12-31 C000530 SGS-PA - Small General Service-PA , 408 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember 4% 2021-01-012021-12-31 C000530 0325 JIM BRANCH, WV, SWITCHBACK, WV, 2, 18, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Kanawha Plant 2021-01-012021-12-31 C000530 , 3 Item(s) Under $50,000 2021-01-012021-12-31 C000530 PJM - #AG1-092  , -772.37 2021-01-012021-12-31 C000530 362.16 - VA, 6173000, 0.0232 2021-01-012021-12-31 C000530 0049 BAILEYSVILLE, WV, KANAWHA #1, WV, 3, 46, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0247 EAST HUNTINGTON, WV, NORTH PROCTORVILLE, OH, 3, 1, 1, 795KCMACSR, 0, 0 2021-01-012021-12-31 C000530 AG2-657 , 1277.92 2021-01-012021-12-31 C000530 Accrued Book Removal Costs 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA (C), Transmission, , 138, 70.5, 13.09, 78,  2021-01-012021-12-31 C000530 BROCKWAY GLASS - VA, Distribution, , 69, 4, , 9.38,  2021-01-012021-12-31 C000530 WURNO - VA (A), Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 FOREST (AP) - VA, Distribution, , 138, 13.09, , 42.4,  2021-01-012021-12-31 C000530 ATKINS - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 CAPITOL HILL 46KV - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 Other Operating Revenues, I&M , -305346 2021-01-012021-12-31 C000530 MOSELEY - VA, Transmission, , 138, 70.5, 13.09, 1674,  2021-01-012021-12-31 C000530 FULKS - WV, Distribution, , 34.5, 34.5, 6.5, 30,  2021-12-31 C000530 SPORN 138KV - WV, Transmission, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 BORDERLAND - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 0258 OPOSSUM CREEK, VA, PEAKSVIEW, VA, 2, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HUFF CREEK - WV, Transmission, , 138, 69, 46, 130,  2021-12-31 C000530 AE1-108 , 39996.39ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0426 BIG SANDY, KY, INEZ A&B, KY, 3, 8, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0517 Town Creek, Progress Park, 2, 7, 1, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 RIPLEY - WV, Distribution, , 69, 13.09, , 12.5,  2021-01-012021-12-31 C000530 CHEMICAL - WV, Transmission, , 138, 46, , 290,  2021-12-31 C000530 PJM - #AE2-280  , -38.73ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 SFAS 109 Deferred Federal Income Tax 2020-12-31 C000530 GLADE - VA, Distribution, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 316 - Amos U1&2, 5493000, P61Y, 0.0508 2021-01-012021-12-31 C000530 ROANOKE (AP) - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 MEADOWVIEW - VA, Distribution, , 138, 69, 34.5, 56,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 12, , 12.5,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember AE1-064 , 4899.32 2021-01-012021-12-31 C000530 Other License And Fees Tax, WV, 2020 , 2021-01-012021-12-31 C000530 ROANOKE ELECTRIC STEEL - VA, Distribution, , 138, 34.5, , 16.67,  2021-12-31 C000530 BAILEYSVILLE - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 0380 FALLING BRANCH, MERRIMAC, 1, 6, 1, 1033 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Local Tax, WV, 2020 , 3017048 2021-01-012021-12-31 C000530 2,000 shares common stock 2020-12-31 C000530 0401A CINDERELLA LOOP, WV, , 3, 0, 1, 1035KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 334 - London Hydro, 1923000, 0.0216 2021-01-012021-12-31 C000530 FLOYD - VA, Transmission, , 138, 13.09, , 10.5,  2021-01-012021-12-31 C000530 West Virginia Broadband Filing 2021-12-31 C000530 JUBAL EARLY - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 AG1-528 , 1596.64ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0008A KANAWHA, WV, MATT FUNK, VA, 3, 8, 1, 1563KCM ACAR, 0, 0 2021-01-012021-12-31 C000530 BLUE PENNANT - WV, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 3,000 shares common stock 2020-12-31 C000530 MINK SHOALS - WV, Distribution, , 69, 13.09, , 20,  2021-12-31 C000530 MORRIS NOVELTY - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-12-31 C000530 Franchise Tax, NC, 2021 , 2100 2021-12-31 C000530 0541 IRONTO EXTENSION, , 1, 0, 2, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WV Vegetation Management Program Costs - Rate Order: WV PSC Case 13-0557-E-P - Rate Order: WV PSC Case 14-1152-E-42T 2021-01-012021-12-31 C000530 KINGSPORT, RQ, 23 2021-01-012021-12-31 C000530 315 - Little Broad Mtn, 65000, P0Y, 0.0376 2021-01-012021-12-31 C000530 FLETCHERS RIDGE - VA, Distribution, , 138, 13.09, , 10.5,  2021-12-31 C000530 CLENDENIN - WV, Transmission, , 46, 34.5, 20.9, 25,  2021-01-012021-12-31 C000530 PRICES FORK - VA, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 AMU2 Air Heater Basket Replace 2021-01-012021-12-31 C000530 Notes Receivable from Associated Companies 2021-01-012021-12-31 C000530 INDEPENDENCE - VA, Distribution, , 69, 34.5, , 20,  2021-12-31 C000530 HYDRO-ELECTRIC 2021-01-012021-12-31 C000530 Sales And Use Tax, OH, 2020 , 2267 2021-01-012021-12-31 C000530 Income Tax, TN, 2017 , 2020-12-31 C000530 ferc:ElectricUtilityMember 0 2021-01-012021-12-31 C000530 BLACKWATER - VA, Distribution, , 34.5, 12, , 20,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 34, , 20,  2021-12-31 C000530 RBC CAPITAL MARKET, LLC, OS, NOTE 1 2021-01-012021-12-31 C000530 0210 BAILEYSVILLE, WV, WYOMING, WV, 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Amos 1&2 DSI Project 2021-01-012021-12-31 C000530 AF1-323 , 54430.14 2021-01-012021-12-31 C000530 SOLITE - VA, Distribution, , 69, 12, , 5.25,  2021-12-31 C000530 0129 PHILPOTT TAP, VA, , 1, 0, 1, 4/0KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 WITT - VA, Distribution, , 69, 4.36, , 12.5,  2021-12-31 C000530 Glen Lyn Unit 6 2021-01-012021-12-31 C000530 Income Tax, WV, 2020 , 2020-12-31 C000530 ferc:ElectricUtilityMember MT HP TURBINE CP REFURBISH 2021-01-012021-12-31 C000530 MOUNT AIRY - VA, Distribution, , 138, 34.5, , 20,  2021-01-012021-12-31 C000530 RSE - Residential Emp. , 69062 2021-01-012021-12-31 C000530 0241A HUFFMAN, VA, JACKSONS FERRY, VA, 1, 8, 0, , 0, 0 2021-01-012021-12-31 C000530 Local Tax, WV, 2020 , 3017048 2020-12-31 C000530 APCO AMI Project WV 2021-01-012021-12-31 C000530 DISMAL RIVER - VA, Distribution, , 69, 12, , 10.5,  2021-12-31 C000530 GREENBRIER METERING - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Increases (Decreases) Due to Miscellaneous Paid-In Capital 2021-01-012021-12-31 C000530 ATKINS - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 ferc:ElectricUtilityMember T/AP/NERC Physical Security 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO - T Work Supplemental 2021-12-31 C000530 0225 AMOS, SPORN, 3, 0, 0, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember DSIT ENTRY - NORMALIZED 2021-12-31 C000530 GALAX - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 Other State Tax, WV, 2020 , 1565569 2020-12-31 C000530 ICAP ENERGY LLC, OS, NOTE 1 2021-01-012021-12-31 C000530 LAYLAND - WV, Distribution, , 69, 13.09, , 2.5,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AF2-106  , 1376.21 2021-01-012021-12-31 C000530 154 - Materials and Supplies 2021-01-012021-12-31 C000530 Undistributed earnings/losses and dividends - Cedar Coal Company 2021-01-012021-12-31 C000530 Ed-Ci-Apco-D Ast Imp 2021-01-012021-12-31 C000530 Undistributed earnings/losses and dividends - Southern Appalachian Coal Company 2021-12-31 C000530 0391 SHEFFIELD LOOP, , 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Therace M. Risch, Vice President 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/Sheridan Trans CI 2021-01-012021-12-31 C000530 0052 BIM TAP, WV, , 1,3, 12, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 AUSTINVILLE - VA, Distribution, , 138, 34.5, , ,  2021-12-31 C000530 CORNING GLASS (AP) - VA, Distribution, , 69, 4, , 8.4,  2021-01-012021-12-31 C000530 Utility Corp Borrowing Program Shared Costs 2021-01-012021-12-31 C000530 GT1A Hot Gas Path 2021-01-012021-12-31 C000530 0, MARMET 2021-12-31 C000530 ferc:ElectricUtilityMember CLH 4 Tailrace Disolved Oxygen 2021-01-012021-12-31 C000530 Materials and Supplies, KPCo , 310746 2021-01-012021-12-31 C000530 0402 SISSON TAP, WV, , 3, 10, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Other (provide details in footnote): 2021-01-012021-12-31 C000530 0400 CANE RIVER, TN CIR-B, NAGEL, TN, 3, 1, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 NORTH CLAYTOR - VA, Transmission, , 138, 69, 34.5, 84,  2021-01-012021-12-31 C000530 SFAS 109 Deferred State Income Tax 2021-12-31 C000530 ferc:ElectricUtilityMember Unemployment Tax, ,  , 76346 2021-01-012021-12-31 C000530 OVEC POWER SCHEDULING, OS, 2021-01-012021-12-31 C000530 Other (provide details in footnote): 2021-01-012021-12-31 C000530 NORTH BECKLEY - WV, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 ferc:OperatingUtilityMember 2020-12-31 C000530 360 - VA (Rights), 24703000, 0.0149 2021-01-012021-12-31 C000530 HILL - VA, Transmission, , 138, 13.09, , 8.4,  2021-12-31 C000530 0238 AMOS, WV, WEST HUNTINGTON, WV, 3, 5, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 LOUDENDALE - WV, Distribution, , 46, 12, , 10.5,  2021-12-31 C000530 RS-LM-TOD Res. Load MGMT , 332 2021-01-012021-12-31 C000530 0424 GLEN LYN, VA, SOUTH PRINCETON, WV, 3, 0, 1, 1351KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Franchise Tax, TN, 2020 , 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other State Tax, WV, 2021 , 32682591 2021-01-012021-12-31 C000530 EAST HUNTINGTON - WV, Transmission, , 138, 69, 34.5, 90,  2021-12-31 C000530 LCP-Large Capacity Power , 2194189 2021-01-012021-12-31 C000530 VA RGGI Deferral 2021-12-31 C000530 FLATWOOD - WV, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 TACKETT CREEK - WV, Distribution, , 138, 13.09, , 25,  2021-01-012021-12-31 C000530 0055 GLEN LYN, VA, WYTHE, VA, 3, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 EAST MONUMENT - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 0567 Glenmary Extension, , 3, 2021-01-012021-12-31 C000530 ferc:DirectPayrollDistributionMember 184 - Clearing Accounts 2021-01-012021-12-31 C000530 GRAVES MILL - VA, Distribution, , 138, 13.09, , 40,  2021-01-012021-12-31 C000530 BARNETT - WV, Distribution, , 69, 13.09, , 20,  2021-01-012021-12-31 C000530 KILLARNEY - WV, Distribution, , 46, 7.2, , 1.16,  2021-01-012021-12-31 C000530 PARK HILL - WV, Distribution, , 138, 13.09, , 22.4,  2021-12-31 C000530 Franchise Tax, TN, 2002 , 2021-12-31 C000530 SCOTTSVILLE (AP) - VA, Transmission, , 46, 13.09, , 9.38,  2021-12-31 C000530 Sales And Use Tax, VA, 2020 , 242451 2020-12-31 C000530 Administrative and General Expenses - Maintenance, AEPSC , 5243052.39 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:HydraulicProductionPlantConventionalMember 2021-01-012021-12-31 C000530 NAGEL - TN, Transmission, , 500, 138, 13.8, ,  2021-12-31 C000530 REUSENS - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 0038 BRADLEY CIR-A, WV, GLEN LYN-HINTON, VA, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0513 WHITEWOOD EXT, , 3, 0, 2, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 1004 KEYWOOD TAP, , 1, 0, 0, , 0, 0 2021-01-012021-12-31 C000530 GLAMORGAN - VA, Distribution, , 34.5, 4, , 9.38,  2021-01-012021-12-31 C000530 DUNBAR - WV, Distribution, , 46, 13.09, , 20,  2021-01-012021-12-31 C000530 SPRIGG - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 DAN RIVER RESEARCH - VA, Distribution, , 69, 12, , 1,  2021-01-012021-12-31 C000530 GLENWOOD (AP) - VA, Distribution, , 13.2, 0.24, , 0.17,  2021-01-012021-12-31 C000530 BELCHER MOUNTAIN - WV, Distribution, , 88, 14, , 4.5,  2021-12-31 C000530 APCO Trans Pre Eng Parent 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other State Tax, OH, 2021 , 16687 2021-01-012021-12-31 C000530 0, LONDON 2021-12-31 C000530 Franchise Tax, TN, 2019 , 2021-01-012021-12-31 C000530 Tranche A-2, 3.7722%, Due 2031 2021-12-31 C000530 Regulatory Services, AEPSC , 1800778.63 2021-01-012021-12-31 C000530 Sales And Use Tax, WV, 2020 , 661831 2020-12-31 C000530 AG2-187 , 1732.23 2021-01-012021-12-31 C000530 DAN RIVER RESEARCH - VA, Distribution, , 7.62, 0.6, , 0.5,  2021-01-012021-12-31 C000530 ferc:OtherLicenseAndFeesTaxMember 2021-12-31 C000530 ferc:LandAndRightsMember Items under $250,000 2021-01-012021-12-31 C000530 WHITESTICK - WV, Distribution, , 46, 12, , 22.4,  2021-01-012021-12-31 C000530 MATT FUNK 138KV - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 HAMPTON - WV, Distribution, , 46, 7.2, , 4.5,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 13.09, , 7.5,  2021-01-012021-12-31 C000530 CURRY - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 TONEY FORK - WV, Distribution, , 46, 12, , 8.4,  2021-01-012021-12-31 C000530 NAGEL - TN, Transmission, , 500, 230, 13.8, 750,  2021-12-31 C000530 0008 CLOVERDALE, VA, MATT FUNK, VA, 3, 19, 0, , 0, 0 2021-01-012021-12-31 C000530 BELVA - WV, Transmission, , 138, 34.5, , 9.38,  2021-12-31 C000530 Labor Accruals - Balance Sheet 2021-12-31 C000530 ferc:ElectricUtilityMember 2021-12-31 C000530 SOUTH BLUEFIELD - WV, Transmission, , 138, 13.09, , 30,  2021-01-012021-12-31 C000530 316 - Clinch River, 6436000, P67Y, 0.0426 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 765, , , , REACTOR 2021-12-31 C000530 SOUTH CHRISTIANSBURG - VA, Transmission, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 336 - Leesville Hydro, 81000, 0.0099 2021-01-012021-12-31 C000530 PJM - #AE2-047  , -57.48ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0528 CAPITOL HILL, CHESTERFIELD AVE, 1, 0, 1, 1033.5 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CROOKED CREEK - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 Distribution Expenses - Operation, AEPSC , 5014790.75 2021-01-012021-12-31 C000530 Mountaineer Coal 2021-01-012021-12-31 C000530 CINDERELLA - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 Sales And Use Tax, TN, 2021 , 1483 2021-12-31 C000530 VA EE-RAC Under Recovery -Case No. PUR - 2017-00126 2021-01-012021-12-31 C000530 Other State Tax, VA, 2021 , 6421600 2021-01-012021-12-31 C000530 MOUNT UNION - VA, Transmission, , 69, 34.5, , 30,  2021-01-012021-12-31 C000530 DEHUE - WV, Distribution, , 46, 13.09, , 9.38,  2021-12-31 C000530 HANCOCK - VA, Transmission, , 138, 69, 34.5, 128.8,  2021-12-31 C000530 Armstrong , 69986 2021-01-012021-12-31 C000530 Defd System Reliability Costs - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023 2021-01-012021-12-31 C000530 SGS-Small General Service , 596 , 60051 2021-01-012021-12-31 C000530 0035 STOTESBURY TAP, WV, , 2, 6, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 A(1)e Generation: Unconventional generation, 2 Item(s) Under $50,000 2021-01-012021-12-31 C000530 LPS-Large Power Service , 303791 2021-01-012021-12-31 C000530 KANAWHA RIVER - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 AG2-190 , 391.91ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 TRANSMISSION, , 2021-01-012021-12-31 C000530 GREENBRIER - WV, Distribution, , 69, 13.09, , 25,  2021-12-31 C000530 WHITESTICK - WV, Distribution, , 46, 12, , 22.4,  2021-12-31 C000530 ferc:ElectricUtilityMember DSIT Normalized 2021-12-31 C000530 CLOVERDALE 765KV - VA (D), Transmission, , 138, 70.5, 13.09, 78,  2021-01-012021-12-31 C000530 WYTHE - VA, Transmission, , 138, 34, , 25,  2021-01-012021-12-31 C000530 APCO CRR Under Recovery 2021-12-31 C000530 Investment in Subsidiary AOCI 2021-01-012021-12-31 C000530 Sales And Use Tax, VA, 2021 , 2637029 2021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AG1-311  , 1603.39 2021-01-012021-12-31 C000530 Virginia Fuel Filing 2021-12-31 C000530 MOUNT AIRY - VA, Distribution, , 138, 34.5, , 20,  2021-12-31 C000530 Sales And Use Tax, OH, 2021 , 115350 2021-12-31 C000530 333 - Niagara Hydro, 640000, 0.0523 2021-01-012021-12-31 C000530 CAPITOL HILL 138KV - WV, Transmission, , 138, 69, 46, 90,  2021-01-012021-12-31 C000530 HARTLAND - WV, Distribution, , 46, 13.09, , 12.5,  2021-12-31 C000530 WV ECS Over Recovery 2021-01-012021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 345, 137.5, 13.8, 450,  2021-01-012021-12-31 C000530 BANCROFT - WV, Transmission, , 138, 13.09, , 25,  2021-01-012021-12-31 C000530 0317 GRANT BRANCH TAP, WV, , 1, 7, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 COVE ROAD - VA, Distribution, , 69, 13.09, , 20,  2021-12-31 C000530 AG1-508 , 3377 2021-01-012021-12-31 C000530 GRUNDY - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 AXTON - VA, Transmission, , 765, 138, 13.8, 750,  2021-01-012021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 345, 137.5, 13.8, 450,  2021-12-31 C000530 0509 CLOVERDALE 765, CLOVERDALE EAST, 2, 0, 1, 4-954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Cedar Coal Company 2021-01-012021-12-31 C000530 Other State Tax, VA, 2018 , 0 2021-01-012021-12-31 C000530 Other License And Fees Tax, WV, 2020 , 2020-12-31 C000530 VA Distribution Substation Carrying Charge Deferral 2021-12-31 C000530 RUSTBURG - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 Sales And Use Tax, TN, 2019 , 112 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Unemployment Tax, WV,  , 194703 2021-01-012021-12-31 C000530 0135 AXTON, VA, DANVILLE #2, VA, 1, 3, 0, , 0, 0 2021-01-012021-12-31 C000530 BECCO - WV, Distribution, , 46, 12, , 9.38,  2021-01-012021-12-31 C000530 0216B BRADLEY, WV, TAMS MOUNTAIN, WV, 3, 1, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CAPITOL HILL 138KV - WV, Transmission, , 138, 13.09, , 20,  2021-12-31 C000530 Unrecovered Fuel Cost - VA 2020-12-31 C000530 INDEPENDENCE - VA, Distribution, , 69, 12, , 10.5,  2021-12-31 C000530 JEWELL RIDGE - VA, Distribution, , 69, 12, , 9.38,  2021-01-012021-12-31 C000530 Income Tax, TN, 2002 , 2021-12-31 C000530 SOUTH BUFFALO - WV, Distribution, , 138, 13.09, , 60,  2021-01-012021-12-31 C000530 APCO Consumer Rate Relief Over Recovery -Rate Order: WV Public Service Commission -Case No. 12-1188-E-PC 2021-01-012021-12-31 C000530 ferc:FederalTaxMember 2021-01-012021-12-31 C000530 0180 HOLSTON, TN, WALTERS, NC, 1, 0, 1, 1033KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, IL, 2020 , 2021-12-31 C000530 MORGANS CUT - VA, Transmission, , 138, 69, 34.5, 84,  2021-01-012021-12-31 C000530 APCo-T Work 1ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 CROSSROADS (AP) - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 0146 FIELDDALE, VA, RIDGEWAY, VA, 1, 10, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, MI, 2021 , 2021-01-012021-12-31 C000530 AMBLER RIDGE - WV, Distribution, , 138, 138, 34.5, 36,  2021-12-31 C000530 PINNACLE CREEK - WV, Distribution, , 138, 34.5, 12, 13.3,  2021-01-012021-12-31 C000530 ferc:MarchMember 0 2021-01-012021-12-31 C000530 JIM BRANCH - WV, Transmission, , 69, 12, , 10,  2021-01-012021-12-31 C000530 Sales And Use Tax, TN, 2020 , 6375 2021-12-31 C000530 Commonwealth of VA , 128993 , 10673717 2021-01-012021-12-31 C000530 0485 JACKSONS FERRY, WYTHE, 2, 5, 1, 1590KCM ACSR/MA2, 0, 0 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 70.5, 46, 90,  2021-01-012021-12-31 C000530 O&M Services for Jointly Owned Facility - Sporn, AEP Generation Resources , -302950 2021-01-012021-12-31 C000530 Factored Customer A/R Bad Debts, AEP Credit Inc. , 4600615.82 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 12, , 15,  2021-01-012021-12-31 C000530 PJM - #AF2-105  , -260.81ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 FRIES - VA, Distribution, , 69, 12, , 10.28,  2021-12-31 C000530 GLEN WHITE - WV, Distribution, , 46, 12, , 6.25,  2021-01-012021-12-31 C000530 Julia A. Sloat, Vice President and Chief Financial Officer 2021-01-012021-12-31 C000530 314 - Mountaineer, 127023000, P60Y, 0.031 2021-01-012021-12-31 C000530 Income Tax, TN, 2021 , 147400 2021-12-31 C000530 MOSELEY, VA, REUSENS, VA, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0063 BROADFORD, VA, SALTVILLE NO.1A&1B, VA, 1, 0, 2, 795KCM ACSR, , 2021-01-012021-12-31 C000530 0025 GLEN LYN, VA (A), SOUTH PRINCETON, WV, 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PEYTONA - WV, Distribution, , 46, 13.09, , 10.5,  2021-12-31 C000530 0502 PROGRESS PARK TAP, , 1, 0, 1, 1590KCM ACSR/MA2, 0, 0 2021-01-012021-12-31 C000530 Equity Carrying Chgs-COVID-19 Costs - VA SCC Case No. PUR-2020-00074 2021-12-31 C000530 ferc:PropertyTaxMember 2021-01-012021-12-31 C000530 0467 CLEARBROOK, VA, MATT FUNK, VA, 1, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PJM - #AG1-314  , 384.85 2021-01-012021-12-31 C000530 BURLINGTON HEIGHTS - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 CLOVERDALE EAST 500KV - VA, Transmission, , 500, 345, 13.8, 3500,  2021-12-31 C000530 TULLETT PREBON AMERICAS CORP., OS, NOTE 1 2021-01-012021-12-31 C000530 0173 ALTAVISTA, VA, LEESVILLE, VA, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, MI, 2018 , 2021-01-012021-12-31 C000530 HANS MEADOW - VA, Distribution, , 69, 12, , 10.5,  2021-12-31 C000530 365 - VA, 591814000, 0.033 2021-01-012021-12-31 C000530 Capital Contributions - Cedar Coal 2020-12-31 C000530 0289 COOPER RIDGE LOOP, VA, , 1, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Income Tax, TN, 2019 , 2020-12-31 C000530 TRAIL FORK - WV, Distribution, , 138, 13.09, , 12.5,  2021-12-31 C000530 CABIN CREEK 46KV - WV, Transmission, , 138, 46.2, , 75,  2021-01-012021-12-31 C000530 NEECE CREEK - VA, Distribution, , 69, 12, , 8.4,  2021-01-012021-12-31 C000530 ROANOKE (AP) - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 Construction Services, KgPCo , 2077631.46 2021-01-012021-12-31 C000530 0028 CABIN CREEK, WV, KANAWHA #1, WV, 3, 0, 1, 556KICM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Deferred Fuel Costs 2021-01-012021-12-31 C000530 311 - Mountaineer, 200421000, P60Y, 0.0292 2021-01-012021-12-31 C000530 MILBURN - WV, Distribution, , 46, 7.2, , 1.5,  2021-01-012021-12-31 C000530 Customer Accounts Expenses, KgPCo , 273344.49 2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember PJM - #AE1-250  , 2171.23 2021-01-012021-12-31 C000530 346 Ceredo Plant, 1270000, 0.037 2021-01-012021-12-31 C000530 WHETSTONE BRANCH - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ALUM RIDGE - VA, Distribution, , 138, 33, 12, 9.38,  2021-12-31 C000530 VCEA Virginia RPS Under Recovery 2021-01-012021-12-31 C000530 0466 IAEGER, WHARNCLIFFE, WV, 3, 6, 1, 556.5KCM26/7 AC, 0, 0 2021-01-012021-12-31 C000530 BOLT - WV, Transmission, , 138, 69, 46, 129,  2021-01-012021-12-31 C000530 CROOKED CREEK - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 CHAUNCEY - WV, Transmission, , 46, 12, , 10.5,  2021-12-31 C000530 SUNDIAL - WV, Transmission, , 138, 69, 46, 90,  2021-12-31 C000530 APCo AMI Project VA 2021-01-012021-12-31 C000530 WV CCR/ELG AFUDC Deferral - Amortization Period: 09/2021 - 08/2022 2021-12-31 C000530 ELK GARDEN - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 VA Sales/Use Tax Surcharge 2020-12-31 C000530 ROANOKE (AP) - VA, Transmission, , 138, 69, 12, 130,  2021-12-31 C000530 SUN MINE - WV, Distribution, , 46, 12, , 20,  2021-12-31 C000530 ferc:ElectricUtilityMemberferc:FranchiseTaxMember 2021-01-012021-12-31 C000530 0296 KAMMER, WV, MOUNTAINEER, WV, 3, 2021-01-012021-12-31 C000530 Franchise Tax, KY, 2020 , 2021-12-31 C000530 ferc:NitrogenOxideMemberferc:CurrentYearMember 2021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, 138, 13.8, 1750,  2021-12-31 C000530 AMEREX POWER, LTD, OS, NOTE 1 2021-01-012021-12-31 C000530 BEALE - WV, Distribution, , 69, 13.09, , 7.5,  2021-01-012021-12-31 C000530 AG2-203 , 1936.07 2021-01-012021-12-31 C000530 RONDA - WV, Distribution, , 46, 12, , 3.75,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCo D (Floyd-Stuart Area) 2021-01-012021-12-31 C000530 PJM Trans Owner Admin Revenue Various Various OLF 2021-01-012021-12-31 C000530 AG1-234 , 2118.32ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 GILBERT - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Unrealized Gain On Forward Commitments 2020-12-31 C000530 353.16, 15542000, 0.0252 2021-01-012021-12-31 C000530 RUSTBURG - VA, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 MCROSS - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Sales And Use Tax, TN, 2020 , 6375 2020-12-31 C000530 POPLAR GAP - WV, Distribution, , 46, 7.2, , 4.5,  2021-12-31 C000530 Property Tax, VA, 2021 , 25977518 2020-12-31 C000530 AG1-136 , 4416.25 2021-01-012021-12-31 C000530 CHERRY CREEK - WV, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 GARDEN CREEK - VA, Transmission, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 SPRIGG - WV, Transmission, , 138, 69, 46, 84,  2021-01-012021-12-31 C000530 PRICES FORK - VA, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 13.2, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 345, 137.5, 13.14, 448,  2021-12-31 C000530 0380 FALLING BRANCH, MERRIMAC, 138, 1, 1, 1033 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0210 BAILYESVILLE, WV, WYOMING, WV, 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SOUTH BUFFALO - WV, Distribution, , 138, 36.2, , 30,  2021-12-31 C000530 West Virginia Broadband Filing 2021-01-012021-12-31 C000530 STARKEY - VA, Distribution, , 138, 13.09, , 40,  2021-01-012021-12-31 C000530 ferc:TransmissionStudiesMember AG2-311 , 872.69 2021-01-012021-12-31 C000530 Income Tax, WV, 2002 , 2021-01-012021-12-31 C000530 Income Tax, WV, 2002 , 2020-12-31 C000530 SKEGGS BRANCH - VA, Transmission, , 138, 69, 4, 30,  2021-01-012021-12-31 C000530 DANVILLE - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 TAZEWELL - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 CLOVERDALE 138KV - VA, Transmission, , 138, 36.2, , 30,  2021-01-012021-12-31 C000530 Trustee Fees 2021-01-012021-12-31 C000530 A(6)a:, 1 Item(s) Under $50,000 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Other State Tax, OH, 2020 , 320 2021-01-012021-12-31 C000530 0179 BOONE DAM, TN, HOLSTON, TN, 1, 8, 0, , 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Berry Hill Station 2021-01-012021-12-31 C000530 Property Tax, OH, 2019 , 1916228 2021-01-012021-12-31 C000530 BASSETT WALKER - VA, Distribution, , 34.5, 7.2, , 5.64,  2021-01-012021-12-31 C000530 MONTEREY - VA, Distribution, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 Rents Billed in Advance 2020-12-31 C000530 0406 JACKSON FERRY, WYOMING, 3, 57, 1, 795 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BANCROFT - WV, Transmission, , 138, 69, 12, 67.2,  2021-12-31 C000530 Income Tax, WV, 2021 , 2021-12-31 C000530 GLENWOOD (AP) - VA, Distribution, , 12, 0.24, , 0.33,  2021-12-31 C000530 SWITCHBACK - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 0219 KINCAID LOOP, WV, , 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0193 BROADFORD, VA, SALTVILLE NO.2, VA, 3, 5, 2, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HANCOCK - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-12-31 C000530 GILBERT - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 331 - Winfield Hydro, 2754000, 0.0297 2021-01-012021-12-31 C000530 MATT FUNK 345KV - VA, Transmission, , 345, 138, 13.1, 672,  2021-12-31 C000530 Investment in Central Coal Company 2021-01-012021-12-31 C000530 Unrecovered Fuel - Common Wealth Virginia - Per Agreement with Commonwealth of Virginia. Effective June 4, 2015. 2021-01-012021-12-31 C000530 0459 GEORGE STREET, LYNBROOK, 2, 2, 1, 1233.6KCM ACSR/TW, 0, 0 2021-01-012021-12-31 C000530 SCOTTSVILLE (AP) - VA, Transmission, , 46, 12, , 5,  2021-01-012021-12-31 C000530 0020A SOUTH PRINCETON, WV, SWITCHBACK A, WV, 3, 15, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Physical & Cyber Security, AEPSC , 1611606.89 2021-01-012021-12-31 C000530 AMHERST - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 Sales And Use Tax, VA, 2020 , 242451 2021-12-31 C000530 MERRIMAC - VA, Transmission, , 138, 69, 13.09, 78,  2021-12-31 C000530 CLAREMONT - WV, Distribution, , 69, 12, , 8.4,  2021-01-012021-12-31 C000530 0277 CABELL LOOP, WV, , 3, 1, 1, 954KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 BROADFORD - VA, Transmission, , 765, , , , REACTOR 2021-12-31 C000530 GLADE - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 APCO - T Work Supplemental 2021-01-012021-12-31 C000530 SPRIGG - WV, Transmission, , 138, 13.2, 12, 9.38,  2021-12-31 C000530 AG1-194 , 1340ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 334 - Leesville Hydro, 1975000, 0.0403 2021-01-012021-12-31 C000530 Income Tax, IL, 2018 , 2021-12-31 C000530 NORTH BECKLEY - WV, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 CAPITALIZED SOFTWARE COST?BOOK 2021-01-012021-12-31 C000530 ferc:OtherLicenseAndFeesTaxMember 2020-12-31 C000530 CHEMICAL - WV, Transmission, , 138, 46, , 290,  2021-01-012021-12-31 C000530 TRI-STATE - WV, Transmission, , 345, 138, 13.8, ,  2021-12-31 C000530 Administrative and General Expenses - Maintenance, KPCo , 291189 2021-01-012021-12-31 C000530 0048 CHAUNCEY TAP, WV, , 3, 4, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 NBV ARO's Retired Plants - Rate Order: VA SCC PUE-2014-0026 - Rate Order: WV PSC 14-1151-E-D 2020-12-31 C000530 ALLEGHENY ELECTRIC COOPERATIVE, OS, NOTE 1 2021-01-012021-12-31 C000530 345 Ceredo Plant, 19434000, 0.0148 2021-01-012021-12-31 C000530 0313 SKEGGS BRANCH, VA, , 1, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 T/AP/Capital Blanket - APCo 2021-01-012021-12-31 C000530 ROANOKE (AP) - VA, Transmission, , 138, 34.5, , 30,  2021-12-31 C000530 Income Tax, MI, 2020 , 2020-12-31 C000530 DUPONT (AP) - VA, Distribution, , 69, 12, , 4.2,  2021-12-31 C000530 APCo VA Major Eq/ Spares-Trans 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Unemployment Tax, KY,  , 317 2021-01-012021-12-31 C000530 0145 ALTAVISTA, VA, REUSENS, VA, 3, 5, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 DUBLIN (AP) - VA, Distribution, , 34.5, 12, , 18.76,  2021-01-012021-12-31 C000530 ELK GARDEN - VA, Distribution, , 138, 36.2, , 30,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember CLH 3 Tailrace Disolved Oxygen 2021-01-012021-12-31 C000530 MCROSS - WV, Distribution, , 69, 34.5, , 30,  2021-01-012021-12-31 C000530 0 2021-01-012021-12-31 C000530 TRAIL FORK - WV, Distribution, , 138, 13.09, , 12.5,  2021-01-012021-12-31 C000530 0160 CLOVERDALE, VA, REUSENS, VA, 3, 36, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0020B SOUTH PRINCETON, WV, SWITCHBACK B, WV, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PJM - #AF2-291  , 764.33 2021-01-012021-12-31 C000530 BAILEYSVILLE - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 ferc:ExciseTaxMember 2021-01-012021-12-31 C000530 CIS-Common Deployment-APC D 2021-01-012021-12-31 C000530 ferc:NitrogenOxideMemberferc:NextTwelveMonthsMember 2021-12-31 C000530 BECKLEY - WV, Distribution, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 Associated Business Development 2021-01-012021-12-31 C000530 POUND - VA, Distribution, , 69, 12, , 6.25,  2021-12-31 C000530 MELROSE - VA, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 Other Deferred Credits 2021-01-012021-12-31 C000530 0179 BOONE DAM, TN, HOLSTON, TN, 3, 0, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PJM - #AG1-494  , 1559.57 2021-01-012021-12-31 C000530 EXPRESSWAY - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:TransmissionSubstationMember 2021-12-31 C000530 DALEWOOD - WV, Distribution, , 138, 13.09, , 20,  2021-01-012021-12-31 C000530 EDWIGHT - WV, Distribution, , 46, 7.2, , 2.49,  2021-12-31 C000530 LSE Formula Rate Defer-Dep 2021-12-31 C000530 392, 9000, 0.0344 2021-01-012021-12-31 C000530 MARSH FORK - WV, Distribution, , 46, 12, , 10.5,  2021-12-31 C000530 346 Dresden - VA AFUDC, 77000, 0.1951 2021-01-012021-12-31 C000530 PJM Trans Distribution & Meter Various Various OS 2021-01-012021-12-31 C000530 BAILEYSVILLE - WV, Transmission, , 138, 46, , 90,  2021-01-012021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 13.2, 0, 0, 0, STATCAP 2021-12-31 C000530 ferc:ElectricUtilityMember Purchase New APCO HDQ Building 2021-12-31 C000530 Franchise Tax, KY, 2019 , 2020-12-31 C000530 WYTHE - VA, Transmission, , 138, 34.5, , 35,  2021-01-012021-12-31 C000530 SPRIGG - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 MORRIS NOVELTY - VA, Distribution, , 34.5, 12, , 3.75,  2021-12-31 C000530 ferc:TransmissionStudiesMember PJM - AF1-173 , -5.37 2021-01-012021-12-31 C000530 MUDLICK - VA, Distribution, , 69, 12, , 22.4,  2021-12-31 C000530 WAYNE - WV, Distribution, , 34.5, 13.09, , 10.5,  2021-01-012021-12-31 C000530 CLAYPOOL HILL - VA, Distribution, , 138, 13.09, , 40,  2021-12-31 C000530 0042 SALTVILLE, VA, TAZEWELL, VA, 3, 21, 1, 1272KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 LOONEY CREEK - VA, Transmission, , 138, 69, 34.5, 90,  2021-12-31 C000530 BURLINGTON HEIGHTS - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 Amos-Gavin 765KV Comm Solvents Tract Land, WV (2639) 2021-01-012021-12-31 C000530 CATAWBA - VA, Transmission, , 138, 69, 34.5, ,  2021-01-012021-12-31 C000530 LUKENS - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 PJM - #AF2-291  , -147.37 2021-01-012021-12-31 C000530 342 Dresden Plant, 26209000, 0.0301 2021-01-012021-12-31 C000530 DARRAH - WV, Transmission, , 138, 34.5, , 30,  2021-12-31 C000530 Estimated , -4207 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO-Tranco Line Rebuild-T 2021-01-012021-12-31 C000530 LICK FORK - VA, Distribution, , 69, 34.5, , 10.5,  2021-01-012021-12-31 C000530 COAL MOUNTAIN - WV, Distribution, , 46, 7.2, , 1.66,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Ds-AP-WVirg-AI Recloser Repl 2021-01-012021-12-31 C000530 MOUNT UNION - VA, Transmission, , 69, 34.5, , 30,  2021-12-31 C000530 0581 Museville Extension, , 1, 2021-01-012021-12-31 C000530 BEALE - WV, Distribution, , 69, 13.09, , 7.5,  2021-12-31 C000530 ferc:ElectricUtilityMember APCo-D Third Party Work Blkt 2021-01-012021-12-31 C000530 Income Tax, TN, 2016 , 2020-12-31 C000530 Carrying Chgs-VA Broadband Pilot - VA SCC Case No. PUR-2019-00145 2021-12-31 C000530 BLUFF POINT WIND ENERGY CENTER, OS, 2021-01-012021-12-31 C000530 CECL adoption of ASC 326 2021-01-012021-12-31 C000530 STOCKTON - VA, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 WV Felman Premium/Discount ENEC 2020-12-31 C000530 REUSENS - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 369 - WV, 177389000, 0.0422 2021-01-012021-12-31 C000530 0018 BERWIND, YUKON, , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 PLANT ROAD - WV, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 CHAUNCEY - WV, Transmission, , 46, 12, , 10.5,  2021-01-012021-12-31 C000530 TOMS FORK - WV, Distribution, , 46, 12, , 4.69,  2021-12-31 C000530 FIELDALE - VA, Transmission, , 138, 70.5, 36.2, 78,  2021-01-012021-12-31 C000530 MULLENS - WV, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 OAK LEVEL - VA, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 SFAS 106 Medicare Subsidy - Amortization period - 1/2013 to 12/2024 2020-12-31 C000530 397, 109036000, 0.0494 2021-01-012021-12-31 C000530 AMOS 765KV - WV, Transmission, , 765, 345, 34.5, 1500,  2021-12-31 C000530 HUFF CREEK - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 PJM - #AF2-302  , 884.42 2021-01-012021-12-31 C000530 BAILEYSVILLE - WV, Transmission, , 46, 12, , 6.25,  2021-01-012021-12-31 C000530 Misc Adjustments , 2021-01-012021-12-31 C000530 AE1-108 , 39996.39 2021-01-012021-12-31 C000530 GS-TOD-General Service TOD , 646 , 49243 2021-01-012021-12-31 C000530 BOONE - WV, Distribution, , 46, 12, , 4.69,  2021-12-31 C000530 0119 CLOVERDALE, VA, GLEN LYN, VA, 3, 20, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Def Lease Assets - Non Taxable 2021-12-31 C000530 ferc:NonUtilityMember Others 2021-01-012021-12-31 C000530 BANCROFT - WV, Transmission, , 138, 34.5, , 20,  2021-12-31 C000530 PJM - #AE1-130  , 1228.37 2021-01-012021-12-31 C000530 DEARINGTON - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 RIPLEY - WV, Distribution, , 69, 34.5, , 25,  2021-01-012021-12-31 C000530 ferc:FederalTaxMember 2021-12-31 C000530 CAPITOL HILL 138KV - WV, Transmission, , 138, 69, 46, 90,  2021-12-31 C000530 GALAX - VA, Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:OtherStateTaxMember 2021-01-012021-12-31 C000530 PJM - AF1-173 , -5.37 2021-01-012021-12-31 C000530 0434 GRASSY CREEK, VA, HALES BRANCH, VA, 3, 0, 2, 1033.5KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Estimated Barging Bills 2021-01-012021-12-31 C000530 TRI-STATE - WV, Transmission, , 345, 137.5, 13.8, 270,  2021-12-31 C000530 ferc:ElectricUtilityMember APCo-D Service Restoration Blk 2021-12-31 C000530 0, WINFIELD 2021-01-012021-12-31 C000530 0083 RAVENSWOOD, WV, SPORN #4, WV, 3, 0, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 MOSS - VA, Distribution, , 69, 12, , 8.4,  2021-12-31 C000530 GRASSY FORK - WV, Distribution, , 138, 34.5, , 20,  2021-12-31 C000530 URY - WV, Distribution, , 46, 12, , 20,  2021-12-31 C000530 MONETA - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 Materials and Supplies, KgPCo , 586658.59 2021-01-012021-12-31 C000530 TURNER - WV, Transmission, , 69, 35.4, 13.8, 30,  2021-01-012021-12-31 C000530 Consent Decree Surrendersferc:NextTwelveMonthsMemberferc:SulfurDioxideMember 2021-01-012021-12-31 C000530 3827 BRADLEY, LAYLAND, 1, 12, 1, , 0, 0 2021-01-012021-12-31 C000530 Demand Side Management Under Recovery - Rate Order: WV Public Service Commission - Case No: 10-0261-E-GI - Case No: WV PSC Case 15-0301-E-GI 2020-12-31 C000530 TRI-STATE - WV, Transmission, , 345, 138, 13.8, ,  2021-01-012021-12-31 C000530 Income Tax, TN, 2020 , 20300 2020-12-31 C000530 SGS-Small General Service , 2579 , 345788 2021-01-012021-12-31 C000530 ferc:NonUtilityMember Others 2020-12-31 C000530 ferc:OtherUtilityMember 2021-01-012021-12-31 C000530 0507 Cloverdale East, Cloverdale Tie Line No. 1, 1, 0, 1, 2 - 1926.9 KCM AC, 0, 0 2021-01-012021-12-31 C000530 RIPLEY - WV, Distribution, , 138, 69, 13.09, 78,  2021-01-012021-12-31 C000530 FLATWOOD - WV, Distribution, , 138, 34.5, , 30,  2021-12-31 C000530 0295 AMOS, WV, MOUNTAINEER, WV, 3, 47, 1, 1351KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0266 HANCOCK, VA, ROANOKE ELECTRIC STEEL, VA, 1, 0, 0, , 0, 0 2021-01-012021-12-31 C000530 0ferc:Quarter1Member 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember AM CCR/ELG Compliance 2021-01-012021-12-31 C000530 0266 HANCOCK, VA, ROANOKE ELECTRIC STEEL, VA, 3, 1, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 12, , 5.25,  2021-12-31 C000530 STONE BRANCH - WV, Distribution, , 138, 13.09, , 20,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 13.09, , 9.38,  2021-01-012021-12-31 C000530 Undistributed earnings/losses and dividends - Cedar Coal Company 2021-12-31 C000530 344 Dresden Plant, 323056000, 0.0307 2021-01-012021-12-31 C000530 0063 ATKINS, VA, WYTHE CIR B, VA, 3, 0, 1, 556KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 PJM - #AE2-047  , 16425.38ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 0087 DARRAH, WV, TRI STATE, WV, 3, 10, 1, 397KCM, 0, 0 2021-01-012021-12-31 C000530 362.16 - WV, 3754000, 0.0252 2021-01-012021-12-31 C000530 0008 CLOVERDALE, VA, MATT FUNK, VA, 3, 0, 1, 954 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ELM STREET - VA, Distribution, , 34.5, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 PJM - #AG1-528  , 1640.77ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 Under Recovery of PJM True-Up 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember APCO-D Telecom 2021-01-012021-12-31 C000530 Other State Tax, VA, 2017 ,ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 Excise Tax, , 2021 , 16433 2021-12-31 C000530 POLEYARD - WV, Distribution, , 138, 13.09, , 25,  2021-01-012021-12-31 C000530 Virginia Energy Efficiency RAC filing 2021-01-012021-12-31 C000530 Local Tax, , 2019 , 2021-12-31 C000530 EXPRESSWAY - VA, Distribution, , 69, 12, , 42.4,  2021-12-31 C000530 PPL ELECTRIC UTILITIES CORP, OS, NOTE 1 2021-01-012021-12-31 C000530 Central Machine Shop, KPCo , 972875 2021-01-012021-12-31 C000530 Income Tax, IL, 2018 , 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Sales And Use Tax, VA, 2021 , 2637029 2021-01-012021-12-31 C000530 Other State Tax, WV, 2020 , 1565569 2021-01-012021-12-31 C000530 311 - Little Broad Mtn, 267000, P0Y, 0.0362 2021-01-012021-12-31 C000530 RIPLEY - WV, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 HUBBARDSTOWN - WV, Distribution, , 138, 34.5, , 20,  2021-12-31 C000530 PJM - #AE2-140  , 61112.1ferc:TransmissionStudiesMember 2021-01-012021-12-31 C000530 AMOS 765KV - WV, Transmission, , 765, 345, 34.5, ,  2021-01-012021-12-31 C000530 0259 REGIS, VA, MONUMENT, VA, 1, 2, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 SGS-Small General Service , 3617045 2021-01-012021-12-31 C000530 ferc:AfterThreeYearsMemberferc:SulfurDioxideMember 2021-01-012021-12-31 C000530 UPPER BRANCH - WV, Distribution, , 46, 7.2, , 2.01,  2021-01-012021-12-31 C000530 PJM Power Factor Credits Rev Nonaffiliated Various Various OS 2021-01-012021-12-31 C000530 Income Tax, WV, 2019 , 2021-01-012021-12-31 C000530 GALAX - VA (A), Distribution, , 69, 12, , 22.4,  2021-01-012021-12-31 C000530 0101 DEXTER, WV, SPORN CIR B, OH, 3, 9, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMemberferc:UnemploymentTaxMember 2021-01-012021-12-31 C000530 ferc:OperatingUtilityMember 2021-12-31 C000530 PIGEON CREEK - WV, Distribution, , 138, 34.5, , 60,  2021-01-012021-12-31 C000530 DAMASCUS - VA, Distribution, , 69, 12, , 20,  2021-01-012021-12-31 C000530 CROSSROADS (AP) - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 SOPHIA - WV, Transmission, , 46, 0, 0, 0, STATCAP 2021-12-31 C000530 GS-TOD-General Service TOD , 1975 2021-01-012021-12-31 C000530 LOUP CREEK - WV, Distribution, , 46, 12, , 3,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 13.09, , 9.38,  2021-12-31 C000530 Franchise Tax, TN, 2021 , 2021-12-31 C000530 0471 HALLS RIDGE, SOUTH PRINCETON, WV, 3, 0, 1, 1590KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 AUSTINVILLE - VA, Distribution, , 138, 34.5, , ,  2021-01-012021-12-31 C000530 0194 CHESTERFIELD TAP, WV, , , 0, 0, , 0, 0 2021-01-012021-12-31 C000530 Construction Services, I&M , 729671.99 2021-01-012021-12-31 C000530 163 - Stores Expense Undistributedferc:AllocationOfPayrollChargedForClearingAccountsMember 2021-01-012021-12-31 C000530 MATT FUNK 138KV - VA, Transmission, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 356, 734356000, 0.0166 2021-01-012021-12-31 C000530 Franchise Tax, NC, 2018 , 2020-12-31 C000530 ALUM CREEK - WV, Distribution, , 46, 13.09, , 9.38,  2021-01-012021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 69, 34.5, , 20,  2021-12-31 C000530 CLOVERDALE 765KV - VA, Transmission, , 138, 69, 13.1, 84,  2021-12-31 C000530 RIVERVILLE - VA, Distribution, , 138, 0, 0, 0, STATCAP 2021-01-012021-12-31 C000530 185 - ODD Temporary Facilities 2021-01-012021-12-31 C000530 CROSSROADS (AP) - VA, Distribution, , 69, 13.09, , 22.4,  2021-01-012021-12-31 C000530 HANS MEADOW - VA, Distribution, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 Glen Lyn Ash Pond ARO - VA HB443 2021-12-31 C000530 Misc Adjustments , 0 , -294720 2021-01-012021-12-31 C000530 EAST RIVER MOUNTAIN - WV, Distribution, , 138, 34.5, , 9.38,  2021-12-31 C000530 336 - Winfield Hydro, 24000, 0.0209 2021-01-012021-12-31 C000530 ARCHER CREEK - VA, Distribution, , 69, 12, , 10.5,  2021-01-012021-12-31 C000530 PJM - #AE1-121  , 2917.26 2021-01-012021-12-31 C000530 Information Technology, AEPSC , 11140938.72 2021-01-012021-12-31 C000530 PJM - #AF2-382  , 2340.48 2021-01-012021-12-31 C000530 Federal Tax, ,  , 32552283 2021-12-31 C000530 391, 12024000, 0.0321 2021-01-012021-12-31 C000530 Unrecovered Fuel - Common Wealth Virginia - Per Agreement with Commonwealth of Virginia. Effective June 4, 2015. 2020-12-31 C000530 KENOVA - WV, Transmission, , 138, 69, 34.5, 200,  2021-01-012021-12-31 C000530 0386 GARRISON WV, , 1, 0, 2, 795 KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Increases (Decreases) in Other Paid-In Capital 2021-01-012021-12-31 C000530 SHEFFIELD (AP) - VA, Distribution, , 138, 34.5, , 30,  2021-01-012021-12-31 C000530 BLAINE - VA, Distribution, , 138, 13.09, , 8.4,  2021-01-012021-12-31 C000530 NORTH PROCTORVILLE, OH, SPORN, WV, 3, 0, 1, 397KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 0125 CLINCH RIVER, VA, MORELAND DRIVE, TN, 3, 49, 1, 636KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember Property Tax, VA, 2019 , 943 2021-01-012021-12-31 C000530 STONE BRANCH - WV, Distribution, , 138, 34.5, , 25,  2021-12-31 C000530 WEST BASSETT - VA, Transmission, , 69, 0, 0, 0, STATCAP 2021-12-31 C000530 POPLAR GAP - WV, Distribution, , 46, 7.2, , 4.5,  2021-01-012021-12-31 C000530 PHOENIX - VA, Distribution, , 46, 7.2, , 1,  2021-12-31 C000530 JACKSONS FERRY - VA, Transmission, , 765, 500, 13.8, 500,  2021-12-31 C000530 SL-Street Lighting , 54207 , 6883196 2021-01-012021-12-31 C000530 MINNIX MOUNTAIN - WV, Distribution, , 138, 34, , 25,  2021-12-31 C000530 0092 BELLEFONTE, KY, TRI STATE, WV, 3, 4, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 Sales And Use Tax, TN, 2019 , 112 2021-12-31 C000530 MIDWAY (AP) - VA, Distribution, , 69, 4, , 12.25,  2021-01-012021-12-31 C000530 PJM - #AG1-089  , 1483.14 2021-01-012021-12-31 C000530 VA Major Storm Expense - VA SCC Case No. PUR-2020-00015 2021-01-012021-12-31 C000530 Smith Mountain Combination Project #2210 - Proportion of cost of administering the Federal Water Power Act 2021-01-012021-12-31 C000530 ferc:ElectricUtilityMember T/AP/Capital Blanket - APCo 2021-01-012021-12-31 C000530 FAS 109 Deferred State Income Tax 2021-12-31 C000530 0081 RAVENSWOOD, WV, SPORN #1, WV, 3, 1, 1, 795KCM ACSR, 0, 0 2021-01-012021-12-31 C000530 HILL - VA, Transmission, , 138, 69, 34.5, 40,  2021-01-012021-12-31 C000530 COVID-19 Costs - WV General Order: WVPSC 262.4 - VA SCC Case No. PUR-2020-00074 2020-12-31 C000530 PJM - #AE2-140  , 61112.1 2021-01-012021-12-31 C000530 Amos 2021-01-012021-12-31 C000530 SHAWSVILLE - VA, Distribution, , 138, 13.09, , 10.5,  2021-01-012021-12-31 C000530 ferc:ElectricPlantInServiceMember Other Accounts (Specify, details in footnote):ferc:ElectricUtilityMember 2021-01-012021-12-31 C000530 WASENA - VA, Distribution, , 69, 12, , 20,  2021-12-31 C000530 DEHUE - WV, Distribution, , 46, 13.09, , 9.38,  2021-01-012021-12-31 utr:kWh iso4217:USD utr:bbl utr:kV xbrli:pure utr:mi utr:MW utr:bbl utr:Btu utr:kWh iso4217:USD utr:T iso4217:USD utr:Mcf utr:T xbrli:shares utr:MVA iso4217:USD utr:kW utr:Btu xbrli:pure utr:MWh iso4217:USD utr:MMBTU utr:Mcf utr:mi iso4217:USD utr:kWh iso4217:USD
THIS FILING IS
Item 1:
An Initial (Original) Submission
OR
Resubmission No.

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

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

Appalachian Power Company
Year/Period of Report

End of:
2021
/
Q4


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

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

Appalachian Power Company
02 Year/ Period of Report


End of:
2021
/
Q4
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)

1 Riverside Plaza, Columbus, Ohio 43215-2373
05 Name of Contact Person

Jason M. Johnson
06 Title of Contact Person

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

1 Riverside Plaza, Columbus, Ohio 43215-2373
08 Telephone of Contact Person, Including Area Code

614- 716-1000
09 This Report is An Original / A Resubmission

(1)
An Original

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

05/19/2022
Annual 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

Jeffrey W.Hoersdig
02 Title

Assistant Controller
03 Signature

Jeffrey W.Hoersdig
04 Date Signed (Mo, Da, Yr)

05/19/2022
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:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
LIST OF SCHEDULES (Electric Utility)

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
2
1
ScheduleGeneralInformationAbstract
General Information
101
2
ScheduleControlOverRespondentAbstract
Control Over Respondent
102
3
ScheduleCorporationsControlledByRespondentAbstract
Corporations Controlled by Respondent
103
4
ScheduleOfficersAbstract
Officers
104
5
ScheduleDirectorsAbstract
Directors
105
6
ScheduleInformationOnFormulaRatesAbstract
Information on Formula Rates
106
7
ScheduleImportantChangesDuringTheQuarterYearAbstract
Important Changes During the Year
108
8
ScheduleComparativeBalanceSheetAbstract
Comparative Balance Sheet
110
9
ScheduleStatementOfIncomeAbstract
Statement of Income for the Year
114
10
ScheduleRetainedEarningsAbstract
Statement of Retained Earnings for the Year
118
12
ScheduleStatementOfCashFlowsAbstract
Statement of Cash Flows
120
12
ScheduleNotesToFinancialStatementsAbstract
Notes to Financial Statements
122
13
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract
Statement of Accum Other Comp Income, Comp Income, and Hedging Activities
122a
14
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep
200
15
ScheduleNuclearFuelMaterialsAbstract
Nuclear Fuel Materials
202
16
ScheduleElectricPlantInServiceAbstract
Electric Plant in Service
204
17
ScheduleElectricPropertyLeasedToOthersAbstract
Electric Plant Leased to Others
213
18
ScheduleElectricPlantHeldForFutureUseAbstract
Electric Plant Held for Future Use
214
19
ScheduleConstructionWorkInProgressElectricAbstract
Construction Work in Progress-Electric
216
20
ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract
Accumulated Provision for Depreciation of Electric Utility Plant
219
21
ScheduleInvestmentsInSubsidiaryCompaniesAbstract
Investment of Subsidiary Companies
224
22
ScheduleMaterialsAndSuppliesAbstract
Materials and Supplies
227
23
ScheduleAllowanceInventoryAbstract
Allowances
228
24
ScheduleExtraordinaryPropertyLossesAbstract
Extraordinary Property Losses
230a
25
ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract
Unrecovered Plant and Regulatory Study Costs
230b
26
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract
Transmission Service and Generation Interconnection Study Costs
231
27
ScheduleOtherRegulatoryAssetsAbstract
Other Regulatory Assets
232
28
ScheduleMiscellaneousDeferredDebitsAbstract
Miscellaneous Deferred Debits
233
29
ScheduleAccumulatedDeferredIncomeTaxesAbstract
Accumulated Deferred Income Taxes
234
30
ScheduleCapitalStockAbstract
Capital Stock
250
31
ScheduleOtherPaidInCapitalAbstract
Other Paid-in Capital
253
32
ScheduleCapitalStockExpenseAbstract
Capital Stock Expense
254b
33
ScheduleLongTermDebtAbstract
Long-Term Debt
256
34
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract
Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax
261
35
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract
Taxes Accrued, Prepaid and Charged During the Year
262
36
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract
Accumulated Deferred Investment Tax Credits
266
37
ScheduleOtherDeferredCreditsAbstract
Other Deferred Credits
269
38
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract
Accumulated Deferred Income Taxes-Accelerated Amortization Property
272
39
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract
Accumulated Deferred Income Taxes-Other Property
274
40
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract
Accumulated Deferred Income Taxes-Other
276
41
ScheduleOtherRegulatoryLiabilitiesAbstract
Other Regulatory Liabilities
278
42
ScheduleElectricOperatingRevenuesAbstract
Electric Operating Revenues
300
43
ScheduleRegionalTransmissionServiceRevenuesAbstract
Regional Transmission Service Revenues (Account 457.1)
302
44
ScheduleSalesOfElectricityByRateSchedulesAbstract
Sales of Electricity by Rate Schedules
304
45
ScheduleSalesForResaleAbstract
Sales for Resale
310
46
ScheduleElectricOperationsAndMaintenanceExpensesAbstract
Electric Operation and Maintenance Expenses
320
47
SchedulePurchasedPowerAbstract
Purchased Power
326
48
ScheduleTransmissionOfElectricityForOthersAbstract
Transmission of Electricity for Others
328
49
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract
Transmission of Electricity by ISO/RTOs
331
50
ScheduleTransmissionOfElectricityByOthersAbstract
Transmission of Electricity by Others
332
51
ScheduleMiscellaneousGeneralExpensesAbstract
Miscellaneous General Expenses-Electric
335
52
ScheduleDepreciationDepletionAndAmortizationAbstract
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
336
53
ScheduleRegulatoryCommissionExpensesAbstract
Regulatory Commission Expenses
350
54
ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract
Research, Development and Demonstration Activities
352
55
ScheduleDistributionOfSalariesAndWagesAbstract
Distribution of Salaries and Wages
354
56
ScheduleCommonUtilityPlantAndExpensesAbstract
Common Utility Plant and Expenses
356
57
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract
Amounts included in ISO/RTO Settlement Statements
397
58
SchedulePurchasesSalesOfAncillaryServicesAbstract
Purchase and Sale of Ancillary Services
398
59
ScheduleMonthlyTransmissionSystemPeakLoadAbstract
Monthly Transmission System Peak Load
400
60
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract
Monthly ISO/RTO Transmission System Peak Load
400a
61
ScheduleElectricEnergyAccountAbstract
Electric Energy Account
401a
62
ScheduleMonthlyPeakAndOutputAbstract
Monthly Peaks and Output
401b
63
ScheduleSteamElectricGeneratingPlantStatisticsAbstract
Steam Electric Generating Plant Statistics
402
64
ScheduleHydroelectricGeneratingPlantStatisticsAbstract
Hydroelectric Generating Plant Statistics
406
65
SchedulePumpedStorageGeneratingPlantStatisticsAbstract
Pumped Storage Generating Plant Statistics
408
66
ScheduleGeneratingPlantStatisticsAbstract
Generating Plant Statistics Pages
410
0
ScheduleEnergyStorageOperationsLargePlantsAbstract
Energy Storage Operations (Large Plants)
414
67
ScheduleTransmissionLineStatisticsAbstract
Transmission Line Statistics Pages
422
68
ScheduleTransmissionLinesAddedAbstract
Transmission Lines Added During Year
424
69
ScheduleSubstationsAbstract
Substations
426
70
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract
Transactions with Associated (Affiliated) Companies
429
71
FootnoteDataAbstract
Footnote Data
450
StockholdersReportsAbstract
Stockholders' Reports (check appropriate box)
Stockholders' Reports Check appropriate box:

Two copies will be submitted

No annual report to stockholders is prepared


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept.

Jeffrey W. Hoersdig

1 Riverside PlazaColumbus, Ohio 43215-2373
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized.

State of Incorporation:
VA

Date of Incorporation:
1926-03-04

Incorporated Under Special Law:

3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased.

(a) Name of Receiver or Trustee Holding Property of the Respondent:

(b) Date Receiver took Possession of Respondent Property:

(c) Authority by which the Receivership or Trusteeship was created:

(d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated.

Electric - West VirginiaElectric - VirginiaElectric - Tennessee
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements?
(1)
Yes

(2)
No


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.
American Electric Power Company, Inc. - Ownership of 100% of the Common Stock.


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
CORPORATIONS CONTROLLED BY RESPONDENT
  1. Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote.
  2. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved.
  3. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests.
Definitions
  1. See the Uniform System of Accounts for a definition of control.
  2. Direct control is that which is exercised without interposition of an intermediary.
  3. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control.
  4. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.
NameOfCompanyControlledByRespondent
Name of Company Controlled
(a)
CompanyControlledByRespondentKindOfBusinessDescription
Kind of Business
(b)
VotingStockOwnedByRespondentPercentage
Percent Voting Stock Owned
(c)
FootnoteReferences
Footnote Ref.
(d)
1
Cedar Coal Company
Coal Mining - Inactive
100
2
Central Appalachian Coal Company
Coal Mining - Inactive
100
3
Central Coal Company
Coal Mining - Inactive
50
(a)
Footnote
4
Southern Appalachian Coal Company
Coal Mining - Inactive
100


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: FootnoteReferences
Central Coal Company is jointly controlled by Respondent and AEP Generation Resources, also a subsidiary of American Electric Power Company, Inc.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
OFFICERS
  1. Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions.
  2. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.
OfficerTitle
Title
(a)
OfficerName
Name of Officer
(b)
OfficerSalary
Salary for Year
(c)
DateOfficerIncumbencyStarted
Date Started in Period
(d)
DateOfficerIncumbencyEnded
Date Ended in Period
(e)
1
(a)
Footnote


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: OfficerTitle
Summary Compensation Table
The following table provides summary information concerning compensation earned by our Chief Executive Officer, our Chief Financial Officer and the three other most highly compensated executive officers, to whom we refer collectively as the named executive officers.
Name and Principal
Position
Year
Salary ($)(1)
Bonus ($)
Stock Awards
($)(2)
Non-Equity
Incentive
Plan
Compensation
($)(3)
Change in
Pension Value
and Nonqualified
Deferred
Compensation
Earnings
($)(4)
All Other
Compensation
($)(5)
Total ($)
Nicholas K. Akins
Chair of the Board and Chief Executive Officer
2021
1,515,808
9,976,149
2,850,000
461,732
247,526
15,051,215
Julia A. Sloat
Executive Vice President and Chief Financial Officer
2021
602,308
1,628,789
637,350
76,622
58,042
3,003,111
Lisa M. Barton
Executive Vice President and Chief Operating Officer
2021
803,077
2,443,104
890,000
165,173
88,143
4,389,497
David M. Feinberg
Executive Vice President, General Counsel and Secretary
2021
696,669
1,527,000
690,000
93,625
98,652
3,105,946
Charles E. Zebula
Executive Vice President - Portfolio Optimization
2021
579,219
1,323,341
640,000
42,921
71,745
2,657,226
Brian X. Tierney
Former Executive Vice President - Strategy
2021
410,000
2,675,947
732,507
3,818,454
Mark C. McCullough
Former Executive Vice President - Energy Delivery
2021
322,327
1,823,341
1,115,159
3,260,827

(1) Amounts in the salary column are composed of executive salaries earned for the year shown, which include 261 days of pay for 2021. This is one day more than the standard 260 calendar work days and holidays in a year.
(2) The amounts reported in this column reflect the aggregate grant date fair value calculated in accordance with FASB ASC Topic 718 of the performance shares, restricted stock units (RSUs) and unrestricted shares granted under our Long-Term Incentive Plan. See Note 15 to the Consolidated Financial Statements included in our Form 10-K for the year ended December 31, 2021 for a discussion of the relevant assumptions used in calculating these amounts. The number of shares realized and the value of the performance shares, if any, will depend on the Company’s performance during a 3-year performance period. The potential payout can range from 0 percent to 200 percent of the target number of performance shares, plus any dividend equivalents. The value of the 2021 performance shares will be based on three measures: a Board approved cumulative operating earnings per share measure (Cumulative EPS 50%), a total shareholder return measure (Relative TSR 40%) and a carbon free capacity mix (Carbon Free Capacity 10%). The grant date fair value of the 2021 performance shares that are based on Cumulative EPS was computed in accordance with FASB ASC Topic 718 and was measured based on the closing price of AEP’s common stock on the grant date. The maximum amount payable for the 2021 performance shares that are based on Cumulative EPS measured on the grant date was $7,350,035 for Mr. Akins; $1,200,060 for Ms. Sloat; $1,800,012 for Ms. Barton; $1,125,066 for Mr. Feinberg; $975,000 for Mr. Zebula; $1,500,036 for Mr. Tierney; and $975,000 for Mr. McCullough. The maximum amount payable for the 2021 performance shares that are based on Carbon Free Capacity is equal to $1,470,007 for Mr. Akins; $240,012 for Ms. Sloat; $360,002 for Ms. Barton; $225,013 for Mr. Feinberg; $195,000 for Mr. Zebula;
$300,007 for Mr. Tierney; and $195,000 for Mr. McCullough. The grant date fair value of the 2021 performance shares that are based on Relative TSR is calculated using a Monte-Carlo model as of the date of grant, in accordance with FASB ASC Topic 718. Because the performance shares that are based on Relative TSR are subject to market conditions as defined under FASB ASC Topic 718, they did not have a maximum value on the grant date that differed from the grant date fair values presented in the table. Instead, the maximum value is factored into the calculation of the grant date fair value. The values realized from the 2019 performance shares are included in the Option Exercises and Stock Vested for 2021 table.

(3) The amounts shown in this column reflect annual incentive compensation paid for the year shown.

(4) The amounts shown in this column are attributable to the increase in the actuarial values of each of the named executive officer’s combined benefits under AEP’s qualified and non-qualified defined benefit pension plans determined using interest rate and mortality assumptions consistent with those used in the Company’s financial statements. Negative values of ($404,033) and ($269,258) for Messrs. Tierney and McCullough, respectfully, were replaced with $0 for the purposes of the Summary Compensation Table. These negative values were caused by their severance from the company during 2021, which resulted in the removal of projected benefits that would have been attributable to eligible earnings for future years under these plans. See the Pension Benefits for 2021 table and related footnotes for additional information. See Note 8 to the Consolidated Financial Statements included in our Form 10-K for the year ended December 31, 2021 for a discussion of the relevant assumptions. None of the named executive officers received preferential or above-market earnings on deferred compensation.

(5) Amounts shown in the All Other Compensation column for 2021 include: (a) Company matching contributions to the Company’s Retirement Savings Plan, (b) Company matching contributions to the Company’s Supplemental Retirement Savings Plan, (c) perquisites, (d) vacation payout, and (e) severance benefits. The 2021 values for these items are listed in the following table:

Type
Nicholas K.
Akins
Julia A.
Sloat
Lisa M.
Barton
David M.
Feinberg
Charles E.
Zebula
Brian X. Tierney
Mark C. McCullough
Retirement Savings Plan Match
$ 13,05
$ 13,05
$ 13,05
$ 13,05
$ 13,05
$ 13,05
$ 13,05
Supplemental Retirement Savings Plan Match
212,400
31,272
61,373
56,295
46,665
53,097
35,468
Perquisites
22,076
13,720
13,720
29,307
12,030
6,360
6,804
Vacation Payout
41,000
60,837
Severance
619,000
999,000
Total
$ 247,526   $ 58,042   $ 88,143   $ 98,652   $ 71,745   $ 732,507   $ 1,115,159  
(6) Ms. Sloat's compensation is provided only for the years in which she was an executive officer of the Company.

Perquisites provided in 2021 included: financial counseling and tax preparation services and, for Mr. Akins, director’s group travel accident insurance premium. Executive officers may also have the occasional personal use of event tickets when such tickets are not being used for business purposes; however, there is no associated incremental cost. From time-to-time executive officers may receive customary gifts from third parties that sponsor events (subject to our policies on conflicts of interest).

Mr. Akins has entered into an Aircraft Time Sharing Agreement that allows him to use our corporate aircraft for personal use for a limited number of hours each year. The Aircraft Time Sharing Agreement requires Mr. Akins to reimburse the Company for the cost of his personal use of corporate aircraft in accordance with limits set forth in Federal Aviation Administration regulations. Mr. Akins reimbursed the Company all incremental costs incurred in connection with personal flights under the Aircraft Timesharing Agreement including fuel, oil, hangar costs, crew travel expenses, catering, landing fees and other incremental airport fees. Accordingly, no value is shown for these amounts in the Summary Compensation Table. If the aircraft flies empty before picking up or after dropping off Mr. Akins at a destination on a personal flight, the cost of the empty flight is included in the incremental cost for which Mr. Akins reimburses the Company. Since AEP aircraft are used predominantly for business purposes, we do not include fixed costs that do not change in amount based on usage, such as depreciation and pilot salaries.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
DIRECTORS
  1. Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent.
  2. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.
NameAndTitleOfDirector
Name (and Title) of Director
(a)
PrincipalBusinessAddress
Principal Business Address
(b)
MemberOfTheExecutiveCommittee
Member of the Executive Committee
(c)
ChairmanOfTheExecutiveCommittee
Chairman of the Executive Committee
(d)
1
Nicholas K. Akins, Chairman of the Board and Chief Executive Officer
Columbus, Ohio
false
false
2
Lisa M. Barton, Vice President
Columbus, Ohio
false
false
3
Christian T. Beam - President and Chief Operating Officer
Charleston, WV
false
false
4
Paul Chodak, Vice President
Columbus, Ohio
false
false
5
David M. Feinberg, Secretary
Columbus, Ohio
false
false
6
Charles R. Patton, Vice President
Columbus, Ohio
false
false
7
Therace M. Risch, Vice President
Columbus, Ohio
false
false
8
Julia A. Sloat, Vice President and Chief Financial Officer
Columbus, Ohio
false
false
9
Toby L. Thomas, Vice President
New Albany, Ohio
false
false
10
Note: The Respondent does not have an Executive Committee.


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
INFORMATION ON FORMULA RATES
Does the respondent have formula rates?
Yes

No
  1. Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.
RateScheduleTariffNumber
FERC Rate Schedule or Tariff Number
(a)
ProceedingDocketNumber
FERC Proceeding
(b)
1
PJM Interconnection LLC - Attachment H-14
ER17-405


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?
Yes

No
  1. If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.
AccessionNumber
Accession No.
(a)
DocumentDate
Document Date / Filed Date
(b)
DocketNumber
Docket No.
(c)
DescriptionOfFiling
Description
(d)
RateScheduleTariffNumber
Formula Rate FERC Rate Schedule Number or Tariff Number
(e)
1
12/21/2021
ER17-405
AEP PJM OATT Proj Transmission
PJM OATT Attachment H-14
2
11/01/2021
ER17-405
AEP PJM OATT Proj Transmission
PJM OATT Attachment H-14
3
05/25/2021
ER17-405
AEP PJM OATT Proj Transmission
PJM OATT Attachment H-14


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
INFORMATION ON FORMULA RATES - Formula Rate Variances
  1. If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1.
  2. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1.
  3. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts.
  4. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.
PageNumberOfFormulaRateVariances
Page No(s).
(a)
ScheduleOfFormulaRateVariances
Schedule
(b)
ColumnOfFormulaRateVariances
Column
(c)
LineNumberOfFormulaRateVariances
Line No.
(d)
1
204-207
Electric Plant in Service
g
49
2
214
Electric Plant Held for Future Use
d
46
3
216
Construction Work In Progress
b
1
4
219
Accumulated Depreciation
b
21
5
310-311
Sales for Resale
k
1
6
320
Electric Operations & Maintenance Expense
b
5
7
320
Electric Operations & Maintenance Expense
b
25
8
320
Electric Operations & Maintenance Expense
b
31
9
321
Electric Operations & Maintenance Expense
b
93
10
323
Electric Operations & Maintenance Expense
b
185
11
336
Depreciation Expense
b
7
12
354
Distribution of Wages and Salaries
b
28


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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.
Date Acquired
Or Extended
Community
(full name)
Period of Franchise & Termination
(month/day/year)
Consideration
($ amount or “None”)
Automatic Renewal on January 05, 2021

Town of Vinton, Virginia
Twenty (20) years expiring January 05, 2041

$1,000.00
Automatic Renewal on Aug 16, 2021

City of Lynchburg, Virginia

Five (5) years expiring Aug 16, 2026

None

Automatic Renewal on Aug 09, 2021

Town of Saltville, Virginia

Forty (40) years expiring Aug 09, 2061

$1,000.00



None
Appalachian Power Company (BU 150) acquired the Redeye Station and Line Assets from Altavista Solar, LLC during September 2021 Business
None
Senior Unsecured Notes $400M, VA State Authority: PUR-2019-00177
TN State Authority: Docket No. 19-00102, FERC Authority: N/A, Issued: 3/11/2021
Maturity: 4/1/2031

Senior Unsecured Notes $100M, VA State Authority: PUR-2019-00177
TN State Authority: Docket No. 19-00102, FERC Authority: N/A, Issued: 3/17/2021
Maturity: 4/1/2031
None
(FERC) AEP 2021 Q2 Labor / Wage Negotiations Status – June 30, 2021
Effective Date
Status
Business Unit
Operating Company, Location
Union Local #
Contract
Or
Wages
Total Personnel Represented
Settlement Amount %
4/1/21
Previously Negotiated and Ratified
Appalachian Power (Wires and Gen)
IBEW 978
(11 CBA’s)
Wages
397
2.5%
5/1/21
Previously Negotiated and Ratified
Appalachian Power
John Amos Plant
USW 8621
Wages
176
2.5%
Please refer to the Notes to Financial Statements Pages 122-123
None
Not used
Julia A. Sloat, elected as Director & Chief Financial Officer effective 1/1/2021
Julie A. Sherwood, elected as Treasurer effective 1/1/2021
Daniel E. Mueller, elected as Assistant Vice President – Tax effective 3/24/2021
Scott P. Moore, elected as Vice President effective 5/19/2021
Christian T. Beam, elected as Director effective 5/2/2021
Wade A. Smith, resigned as Vice President on 5/1/2021
Therace M. Risch, elected as Director & Vice President effective from 7/03/2021
Toby L. Thomas, elected as Director & Vice President effective 7/31/2021
Charles E. Zebula, elected as Vice President effective 7/03/2021
Mark C. McCullough, resigned as Director and Vice president effective 7/30/2021
Brian X. Tierney, resigned as Director and Vice President effective 7/1/2021
Proprietary capital ratio exceeds 30%


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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
16,401,181,030
15,655,993,813
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200
471,403,315
485,037,217
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Enter Total of lines 2 and 3)
16,872,584,345
16,141,031,030
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)
200
5,765,578,075
5,412,843,611
6
UtilityPlantNet
Net Utility Plant (Enter Total of line 4 less 5)
11,107,006,270
10,728,187,419
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)
11,107,006,270
10,728,187,419
15
OtherElectricPlantAdjustments
Utility Plant Adjustments (116)
16
GasStoredUndergroundNoncurrent
Gas Stored Underground - Noncurrent (117)
17
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
18
NonutilityProperty
Nonutility Property (121)
13,295,371
13,295,545
19
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Prov. for Depr. and Amort. (122)
5,192,401
5,198,888
20
InvestmentInAssociatedCompanies
Investments in Associated Companies (123)
21
InvestmentInSubsidiaryCompanies
Investment in Subsidiary Companies (123.1)
224
4,641,308
5,257,849
23
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
228
22,004,289
22,044,921
24
OtherInvestments
Other Investments (124)
205,198,349
232,115,959
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)
216,680,819
146,605,010
30
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
123,974
31
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
32
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Lines 18-21 and 23-31)
456,627,735
414,244,369
33
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
34
CashAndWorkingFunds
Cash and Working Funds (Non-major Only) (130)
35
Cash
Cash (131)
2,496,136
5,766,797
36
SpecialDeposits
Special Deposits (132-134)
89,614,237
18,832,104
37
WorkingFunds
Working Fund (135)
38
TemporaryCashInvestments
Temporary Cash Investments (136)
39
NotesReceivable
Notes Receivable (141)
40
CustomerAccountsReceivable
Customer Accounts Receivable (142)
166,951,944
154,423,761
41
OtherAccountsReceivable
Other Accounts Receivable (143)
162,884
295,970
42
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
1,629,934
3,060,608
43
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
44
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Assoc. Companies (146)
127,358,814
61,647,732
45
FuelStock
Fuel Stock (151)
227
61,380,905
182,954,925
46
FuelStockExpensesUndistributed
Fuel Stock Expenses Undistributed (152)
227
5,704,904
10,651,652
47
Residuals
Residuals (Elec) and Extracted Products (153)
227
6,791
4,821
48
PlantMaterialsAndOperatingSupplies
Plant Materials and Operating Supplies (154)
227
109,053,857
99,205,804
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
22,794,207
22,422,049
53
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
228
22,004,289
22,044,921
54
StoresExpenseUndistributed
Stores Expense Undistributed (163)
227
55
GasStoredCurrent
Gas Stored Underground - Current (164.1)
56
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57
Prepayments
Prepayments (165)
7,799,236
6,969,431
58
AdvancesForGas
Advances for Gas (166-167)
59
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
365
291
60
RentsReceivable
Rents Receivable (172)
1,277,779
1,345,780
61
AccruedUtilityRevenues
Accrued Utility Revenues (173)
54,013,000
80,063,530
62
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
63
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
41,975,558
20,103,677
64
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
123,974
65
DerivativeInstrumentAssetsHedges
Derivative Instrument Assets - Hedges (176)
2,386,411
66
DerivativeInstrumentAssetsHedgesLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67
CurrentAndAccruedAssets
Total Current and Accrued Assets (Lines 34 through 66)
666,956,394
641,845,232
68
DeferredDebitsAbstract
DEFERRED DEBITS
69
UnamortizedDebtExpense
Unamortized Debt Expenses (181)
28,847,639
27,812,762
70
ExtraordinaryPropertyLosses
Extraordinary Property Losses (182.1)
230a
79,082,399
82,485,469
71
UnrecoveredPlantAndRegulatoryStudyCosts
Unrecovered Plant and Regulatory Study Costs (182.2)
230b
72
OtherRegulatoryAssets
Other Regulatory Assets (182.3)
232
1,129,473,642
883,585,010
73
PreliminarySurveyAndInvestigationCharges
Prelim. Survey and Investigation Charges (Electric) (183)
5,487,298
1,597,802
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)
144,576
28,199
77
TemporaryFacilities
Temporary Facilities (185)
78
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
92,952,422
84,954,431
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)
78,193,342
82,060,027
82
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234
488,763,374
494,843,653
83
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
84
DeferredDebits
Total Deferred Debits (lines 69 through 83)
1,902,944,692
1,657,367,353
85
AssetsAndOtherDebits
TOTAL ASSETS (lines 14-16, 32, 67, and 84)
14,133,535,091
13,441,644,373


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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
260,457,768
260,457,768
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
1,828,626,950
1,828,626,950
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
2,538,035,582
2,251,598,527
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118
3,463,213
3,463,213
13
ReacquiredCapitalStock
(Less) Reaquired Capital Stock (217)
250
14
NoncorporateProprietorship
Noncorporate Proprietorship (Non-major only) (218)
15
AccumulatedOtherComprehensiveIncome
Accumulated Other Comprehensive Income (219)
122(a)(b)
24,379,199
7,921,383
16
ProprietaryCapital
Total Proprietary Capital (lines 2 through 15)
4,648,036,287
4,345,141,416
17
LongTermDebtAbstract
LONG-TERM DEBT
18
Bonds
Bonds (221)
256
200,079,231
225,471,913
19
ReacquiredBonds
(Less) Reaquired Bonds (222)
256
20
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256
21
OtherLongTermDebt
Other Long-Term Debt (224)
256
4,782,910,721
4,650,495,969
22
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
23
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Debit (226)
15,252,087
14,079,660
24
LongTermDebt
Total Long-Term Debt (lines 18 through 23)
4,967,737,864
4,861,888,222
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases - Noncurrent (227)
80,452,977
98,735,304
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
5,159,571
6,321,471
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
10,921,258
10,293,071
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
584,830
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
2,137
100,332
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
34
AssetRetirementObligations
Asset Retirement Obligations (230)
404,622,571
313,144,616
35
OtherNoncurrentLiabilities
Total Other Noncurrent Liabilities (lines 26 through 34)
501,158,515
429,179,625
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
NotesPayable
Notes Payable (231)
38
AccountsPayable
Accounts Payable (232)
262,186,705
211,962,187
39
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
199,282,967
18,639,896
40
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
118,534,546
97,012,806
41
CustomerDeposits
Customer Deposits (235)
73,923,266
77,819,096
42
TaxesAccrued
Taxes Accrued (236)
262
81,703,750
100,698,572
43
InterestAccrued
Interest Accrued (237)
47,869,294
49,916,651
44
DividendsDeclared
Dividends Declared (238)
45
MaturedLongTermDebt
Matured Long-Term Debt (239)
46
MaturedInterest
Matured Interest (240)
47
TaxCollectionsPayable
Tax Collections Payable (241)
4,696,419
4,508,999
48
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
51,649,564
76,064,233
49
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
22,748,700
22,269,913
50
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
819,652
1,244,910
51
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
2,137
100,332
52
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
3,449,077
53
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54
CurrentAndAccruedLiabilities
Total Current and Accrued Liabilities (lines 37 through 53)
863,412,725
663,486,007
55
DeferredCreditsAbstract
DEFERRED CREDITS
56
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
57
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
266
306,934
318,791
58
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
59
OtherDeferredCredits
Other Deferred Credits (253)
269
32,700,650
34,315,356
60
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
821,478,629
857,824,376
61
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reaquired Debt (257)
62
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accum. Deferred Income Taxes-Accel. Amort.(281)
272
143,723,636
152,137,429
63
AccumulatedDeferredIncomeTaxesOtherProperty
Accum. Deferred Income Taxes-Other Property (282)
1,507,749,250
1,406,964,317
64
AccumulatedDeferredIncomeTaxesOther
Accum. Deferred Income Taxes-Other (283)
647,230,599
690,388,834
65
DeferredCredits
Total Deferred Credits (lines 56 through 64)
3,153,189,698
3,141,949,103
66
LiabilitiesAndOtherCredits
TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)
14,133,535,089
13,441,644,373


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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
3,141,973,453
2,857,247,281
3,141,973,453
2,857,247,281
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
320
1,594,399,774
1,379,799,825
1,594,399,774
1,379,799,825
5
MaintenanceExpense
Maintenance Expenses (402)
320
265,523,828
226,820,833
265,523,828
226,820,833
6
DepreciationExpense
Depreciation Expense (403)
336
497,621,638
511,822,169
497,621,638
511,822,169
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336
3,452,247
2,978,914
3,452,247
2,978,914
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336
41,256,314
34,704,003
41,256,314
34,704,003
9
AmortizationOfElectricPlantAcquisitionAdjustments
Amort. of Utility Plant Acq. Adj. (406)
336
10
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts
Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
4,094,894
4,094,894
4,094,894
4,094,894
11
AmortizationOfConversionExpenses
Amort. of Conversion Expenses (407.2)
12
RegulatoryDebits
Regulatory Debits (407.3)
8,179,991
4,190,246
8,179,991
4,190,246
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
524,237
48,957,692
524,237
48,957,692
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262
148,738,854
149,716,603
148,738,854
149,716,603
15
IncomeTaxesOperatingIncome
Income Taxes - Federal (409.1)
262
9,367,566
27,790,428
9,367,566
27,790,428
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes - Other (409.1)
262
2,592,072
8,378,083
2,592,072
8,378,083
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision for Deferred Income Taxes (410.1)
234, 272
449,012,755
1,193,050,491
449,012,755
1,193,050,491
18
ProvisionForDeferredIncomeTaxesCreditOperatingIncome
(Less) Provision for Deferred Income Taxes-Cr. (411.1)
234, 272
431,854,357
1,222,271,015
431,854,357
1,222,271,015
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adj. - Net (411.4)
266
9,420
170,592
9,420
170,592
20
GainsFromDispositionOfPlant
(Less) Gains from Disp. of Utility Plant (411.6)
531,291
486,254
531,291
486,254
21
LossesFromDispositionOfServiceCompanyPlant
Losses from Disp. of Utility Plant (411.7)
6,086
24,345
6,086
24,345
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
59
102,181
59
102,181
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
24
AccretionExpense
Accretion Expense (411.10)
1,381,730
8,917,931
1,381,730
8,917,931
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)
2,592,708,386
2,280,301,030
2,592,708,386
2,280,301,031
27
NetUtilityOperatingIncome
Net Util Oper Inc (Enter Tot line 2 less 25)
549,265,067
576,946,250
549,265,067
576,946,250
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)
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
684
990
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
21,806
15,157
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
37
InterestAndDividendIncome
Interest and Dividend Income (419)
898,177
1,345,705
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
15,567,699
14,619,304
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
637,741
97,249
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
59,242
240,546
41
OtherIncome
TOTAL Other Income (Enter Total of lines 31 thru 40)
17,183,980
16,286,657
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
417,560
401,163
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
45
Donations
Donations (426.1)
1,708,560
1,241,165
46
LifeInsurance
Life Insurance (426.2)
47
Penalties
Penalties (426.3)
212,059
698,326
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Exp. for Certain Civic, Political & Related Activities (426.4)
1,680,552
1,424,584
49
OtherDeductions
Other Deductions (426.5)
6,758,655
6,111,130
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
10,353,267
8,479,716
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262
314,263
320,687
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262
4,423,826
6,077,354
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262
430,325
892,790
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Inc. Taxes (410.2)
234, 272
2,317,737
4,218,526
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Cr. (411.2)
234, 272
4,004,143
1,435,083
57
InvestmentTaxCreditAdjustmentsNonutilityOperations
Investment Tax Credit Adj.-Net (411.5)
2,437
12,984
58
InvestmentTaxCredits
(Less) Investment Tax Credits (420)
59
TaxesOnOtherIncomeAndDeductions
TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)
6,228,731
2,093,417
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
13,059,443
9,900,358
61
InterestChargesAbstract
Interest Charges
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
211,947,638
211,822,330
63
AmortizationOfDebtDiscountAndExpense
Amort. of Debt Disc. and Expense (428)
4,116,805
3,761,971
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reaquired Debt (428.1)
3,866,685
3,800,583
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)
137,743
2,818,980
68
OtherInterestExpense
Other Interest Expense (431)
854,617
2,826,301
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)
7,536,033
7,916,223
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
213,387,455
217,113,942
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
348,937,055
369,732,667
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)
348,937,055
369,732,667


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report


End of:
2021
/
Q4
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
2,233,348,137
2,063,881,888
2
ChangesAbstract
Changes
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
4
AdjustmentsToRetainedEarningsCreditAbstract
Adjustments to Retained Earnings Credit
4.1
AdjustmentsToRetainedEarningsCredit
CECL adoption of ASC 326
7,198
9
AdjustmentsToRetainedEarningsCredit
TOTAL Credits to Retained Earnings (Acct. 439)
7,198
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)
348,937,055
369,732,667
17
AppropriationsOfRetainedEarningsAbstract
Appropriations of Retained Earnings (Acct. 436)
17.1
AppropriationsOfRetainedEarnings
Appropriations of Retained Earnings (Acct. 436)
835,594
259,220
17.2
AppropriationsOfRetainedEarnings
Excess Earnings on Hydro Licensed Projects
22
AppropriationsOfRetainedEarnings
TOTAL Appropriations of Retained Earnings (Acct. 436)
835,594
259,220
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
62,500,000
200,000,000
36
DividendsDeclaredCommonStock
TOTAL Dividends Declared-Common Stock (Acct. 438)
62,500,000
200,000,000
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)
2,518,949,598
2,233,348,137
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)
19,085,984
18,250,390
47
AppropriatedRetainedEarningsIncludingReserveAmortization
TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
19,085,984
18,250,390
48
RetainedEarnings
TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)
2,538,035,582
2,251,598,527
UnappropriatedUndistributedSubsidiaryEarningsAbstract
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49
UnappropriatedUndistributedSubsidiaryEarnings
Balance-Beginning of Year (Debit or Credit)
3,463,213
3,463,213
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)
3,463,213
3,463,213


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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)
348,937,055
369,732,667
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
546,425,093
553,599,980
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of Regulatory Debits and Credits
7,655,755
44,767,446
5.2
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Customer Deposits
3,895,830
7,977,923
8
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
15,471,992
26,437,082
9
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustment (Net)
11,857
183,576
10
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
79,468,006
9,498,073
11
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
116,670,745
38,279,765
12
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
372,157
87,830
13
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
15,762,573
12,482,084
14
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
65,247,305
96,551,619
15
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
28,775,303
12,022,095
16
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
15,567,699
14,619,304
17
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
18
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other (provide details in footnote):
18.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other (provide details in footnote):
(a)
105,960,212
14,188,912
18.2
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Over/Under Recovered Fuel, net
195,996,845
37,245,483
22
NetCashFlowFromOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)
613,178,605
707,702,272
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)
859,309,687
784,634,596
27
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
28
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
29
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
10,598
21,477
30
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
15,567,699
14,619,304
31
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other (provide details in footnote):
31.1
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription
Other (provide details in footnote):
31.2
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription
Aquired Assets
684,622
771,426
34
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 26 thru 33)
844,437,208
770,808,195
36
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
37
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
(b)
6,497,418
6,935,976
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
43,494
52
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
53
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other (provide details in footnote):
53.1
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Other (provide details in footnote):
(c)
8,748,660
2,605,552
53.2
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
(Increase) Decrease in other special deposits
6,470,985
158,275
53.3
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Notes Receivable from Associated Companies
57
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)
835,662,115
761,064,898
59
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
60
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
61
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Long-Term Debt (b)
500,000,000
615,350,000
62
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Preferred Stock
63
ProceedsFromIssuanceOfCommonStockFinancingActivities
Common Stock
64
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other (provide details in footnote):
64.1
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription
Other (provide details in footnote):
64.2
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription
Long-Term Issuance Costs
5,998,004
8,484,216
66
NetIncreaseInShortTermDebt
Net Increase in Short-Term Debt (c)
67
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
67.1
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Proceeds on Capital Leaseback
741,069
741,695
67.2
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Notes Payable to Associates Companies
180,643,071
70
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total 61 thru 69)
675,386,136
607,607,479
72
PaymentsForRetirementAbstract
Payments for Retirement of:
73
PaymentsForRetirementOfLongTermDebtFinancingActivities
Long-term Debt (b)
392,977,930
140,314,903
74
PaymentsForRetirementOfPreferredStockFinancingActivities
Preferred Stock
75
PaymentsForRetirementOfCommonStockFinancingActivities
Common Stock
76
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.2
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Notes Payable to Associates Companies
218,084,418
78
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
80
DividendsOnPreferredStock
Dividends on Preferred Stock
81
DividendsOnCommonStock
Dividends on Common Stock
62,500,000
200,000,000
83
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)
219,908,206
49,208,159
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)
2,575,304
4,154,468
88
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
22,677,565
26,832,033
90
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
20,102,261
22,677,565


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
2021
Cash Flow
Incr / (Decr)
2020
Cash Flow
Incr / (Decr)
Utility Plant, Net $ (52,588,847) $ (42,872,559)
Property and Investments, Net 26,921,895  24,160,608 
Margin Deposits (63,615,793) 2,621,912 
Mark-to-Market of Risk Management Contracts (22,297,139) 18,818,615 
Prepayments (8,016,740) (13,845,073)
Accrued Utility Revenues, Net 26,050,530  (20,371,575)
Miscellaneous Current and Accr Assets —  14,500,000 
Unamortized Debt Expense 2,760,127  2,428,222 
Other Deferred Debits, Net (4,092,645) 7,011,262 
Proprietary Capital, Net —  (7,198)
Other Comprehensive Income, Net 7,497,475  (891,858)
Unamortized Discount/Premium on Long-Term Debt 1,030,573  895,490 
Accumulated Provisions - Misc (878,808) 6,842,236 
Current and Accrued Liabilities, Net (21,127,199) (8,320,752)
Other Deferred Credits, Net 2,396,359  (5,158,241)
Total $ (105,960,212) $ (14,188,912)
(b) Concept: ProceedsFromDisposalOfNoncurrentAssets
2021
Cash Flow
Incr / (Decr)
2020
Cash Flow
Incr / (Decr)
Sale of transformers between various operating companies $ 423,504  $ 2,387,731 
Sale of meters between various operating companies 784,918  3,510,391 
Sale of land to Vogel & Cromwell 284,346  910,354 
Sale of 23.24 +/- acres located in Buffalo Power Plant site —  127,500 
Sale of spare GSU transformer 3,265,642  — 
Transco Transfer of Assets 1,739,008  — 
Total $ 6,497,418   $ 6,935,976  
(c) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities
2021
Cash Flow
Incr / (Decr)
2020
Cash Flow
Incr / (Decr)
CIAC Proceeds $ 8,748,660  $ 2,605,552 
Total $ 8,748,660   $ 2,605,552  

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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.
INDEX OF NOTES TO FINANCIAL STATEMENTS
Glossary of Terms for Notes
1.Organization and Summary of Significant Accounting Policies
2.New Accounting Standards
3.Comprehensive Income
4.Rate Matters
5.Effects of Regulation
6.Commitments, Guarantees and Contingencies
7.Benefit Plans
8.Business Segments
9.Derivatives and Hedging
10.Fair Value Measurements
11.Income Taxes
12.Leases
13.Financing Activities
14.Related Party Transactions
15.Property, Plant and Equipment
16.Revenue from Contracts with Customers
17.FERC Order NO. 784-A
GLOSSARY OF TERMS FOR NOTES

When the following terms and abbreviations appear in the text of this report, they have the meanings indicated below.
Term Meaning
   
AEP 
American Electric Power Company, Inc., an investor-owned electric public utility holding company which includes American Electric Power Company, Inc. (Parent) and majority-owned subsidiaries and affiliates.
AEP Credit
AEP Credit, Inc., a subsidiary of AEP which securitizes accounts receivable and accrued utility revenues for affiliated electric utility companies.
AEP East Companies
APCo, I&M, KGPCo, KPCo, OPCo and WPCo.
AEP System 
American Electric Power System, an electric system, owned and operated by AEP subsidiaries.
AEPSC
 
American Electric Power Service Corporation, an AEP service subsidiary providing management and professional services to AEP and its subsidiaries.
AEPTCo
 
AEP Transmission Company, LLC, a wholly-owned subsidiary of AEP Transmission Holdco, is an intermediate holding company that owns the State Transcos.
AFUDC Allowance for Equity Funds Used During Construction.
AMIAdvanced Metering Infrastructure.
AMRAutomated Meter Reading.
AOCIAccumulated Other Comprehensive Income.
APCo Appalachian Power Company, an AEP electric utility subsidiary.
ARAM
Average Rate Assumption Method, an IRS approved method used to calculate the reversal of Excess ADIT for rate-making purposes.
AROAsset Retirement Obligations.
CARES ActCoronavirus Aid, Relief, and Economic Security Act signed into law in March 2020.
CCRCoal Combustion Residual.
COVID-19
Coronavirus 2019, a highly infectious respiratory disease. In March 2020, the World Health Organization declared COVID-19 a worldwide pandemic.
CWIPConstruction Work in Progress.
EIS
Energy Insurance Services, Inc., a nonaffiliated captive insurance company.
ELGEffluent Limitation Guidelines.
ENECExpanded Net Energy Cost.
ESP
Electric Security Plans, a PUCO requirement for electric utilities to adjust their rates by filing with the PUCO.
Excess ADITExcess accumulated deferred income taxes.
FACFuel Adjustment Clause.
FASBFinancial Accounting Standards Board.
Federal EPA United States Environmental Protection Agency.
FERC Federal Energy Regulatory Commission.
FTR
Financial Transmission Right, a financial instrument that entitles the holder to receive compensation for certain congestion-related transmission charges that arise when the power grid is congested resulting in differences in locational prices.
GAAPAccounting Principles Generally Accepted in the United States of America.
I&M Indiana Michigan Power Company, an AEP electric utility subsidiary.
IRSInternal Revenue Service.
ITCInvestment Tax Credit.
KGPCo Kingsport Power Company, an AEP electric utility subsidiary.
KPCo Kentucky Power Company, an AEP electric utility subsidiary.
MTMMark-to-Market.
MWhMegawatt-hour.
NOLNet operating losses.
NOx
 Nitrogen oxide.
OATT Open Access Transmission Tariff.
OPCo Ohio Power Company, an AEP electric utility subsidiary.
OPEBOther Postretirement Benefits.
Operating Agreement
Agreement, dated January 1, 1997, as amended, by and among PSO and SWEPCo governing generating capacity allocation, energy pricing, and revenues and costs of third-party sales.  AEPSC acts as the agent.
OTCOver-the-counter.
OVEC Ohio Valley Electric Corporation, which is 43.47% owned by AEP.
Parent
American Electric Power Company, Inc., the equity owner of AEP subsidiaries within the AEP consolidation.
PCAPower Coordination Agreement among APCo, I&M, KPCo and WPCo.
PJM Pennsylvania – New Jersey – Maryland regional transmission organization.
PPAPurchase Power and Sale Agreement.
PSO Public Service Company of Oklahoma, an AEP electric utility subsidiary.
PTCProduction Tax Credits.
Risk Management Contracts
Trading and non-trading derivatives, including those derivatives designated as cash flow and fair value hedges.
ROE
Return on Equity.
RPMReliability Pricing Model.
RTO 
Regional Transmission Organization, responsible for moving electricity over large interstate areas.
SIA
System Integration Agreement, effective June 15, 2000, as amended, provides contractual basis for coordinated planning, operation and maintenance of the power supply sources of the combined AEP.
SPP Southwest Power Pool regional transmission organization.
SSOStandard service offer.
SWEPCo Southwestern Electric Power Company, an AEP electric utility subsidiary.
TA 
Transmission Agreement, effective November 2010, among APCo, I&M, KGPCo, KPCo, OPCo and WPCo with AEPSC as agent.
Tax Reform
On December 22, 2017, President Trump signed into law legislation referred to as the “Tax Cuts and Jobs Act” (the TCJA). The TCJA includes significant changes to the Internal Revenue Code of 1986, including a reduction in the corporate federal income tax rate from 35% to 21% effective January 1, 2018.
TCA 
Transmission Coordination Agreement dated January 1, 1997, by and among, PSO, SWEPCo and AEPSC, in connection with the operation of the transmission assets of the two public utility subsidiaries.
Utility Money Pool 
Centralized funding mechanism AEP uses to meet the short-term cash requirements of certain utility subsidiaries.
Virginia SCC Virginia State Corporation Commission.
WPCo Wheeling Power Company, an AEP electric utility subsidiary.
WVPSC Public Service Commission of West Virginia.
1.  ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

ORGANIZATION

As a public utility, APCo engages in the generation and purchase of electric power, and the subsequent sale, transmission and distribution of that power to approximately 966,000 retail customers in its service territory in southwestern Virginia and southern West Virginia. APCo sells power at wholesale to municipalities.

To minimize the credit requirements and operating constraints when operating within PJM, participating AEP companies, including APCo, agreed to a netting of certain payment obligations incurred by the participating AEP companies against certain balances due to such AEP companies and to hold PJM harmless from actions that any one or more AEP companies may take with respect to PJM.

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Rates and Service Regulation

APCo’s rates are regulated by the FERC, the Virginia SCC and the WVPSC.  The FERC also regulates APCo’s affiliated transactions, including AEPSC intercompany service billings which are generally at cost, under the 2005 Public Utility Holding Company Act and the Federal Power Act.  The FERC also has jurisdiction over certain issuances and acquisitions of securities of the public utility subsidiaries, the acquisition or sale of certain utility assets and mergers with another electric utility or holding company.  The state regulatory commissions also regulate certain intercompany transactions under various orders and affiliate statutes.  Both the FERC and state regulatory commissions are permitted to review and audit the relevant books and records of companies within a public utility holding company system.

The FERC regulates wholesale power markets and wholesale power transactions.  APCo’s wholesale power transactions are generally market-based.  Wholesale power transactions are cost-based regulated when a cost-based contract is negotiated and filed with the FERC or the FERC determines that APCo has “market power” in the region where the transaction occurs.  Wholesale power supply contracts have been entered into with various municipalities and cooperatives that are FERC-regulated, cost-based contracts.  These contracts are generally formula rate mechanisms, which are trued-up to actual costs annually.  

The Virginia SCC and the WVPSC regulate all of the retail distribution operations and rates of APCo’s retail public utility subsidiaries on a cost basis.  They also regulate the retail generation/power supply operations and rates.

The FERC also regulates APCo’s wholesale transmission operations and rates.  Retail transmission rates are based upon the FERC OATT rate when retail rates are unbundled in connection with restructuring.  Retail transmission rates are based on formula rates included in the PJM OATT that are cost-based and are unbundled in Virginia. Bundled retail transmission rates are regulated, on a cost basis, by the Virginia SCC and the WVPSC.

In West Virginia, APCo and WPCo provide retail electric service at bundled rates approved by the WVPSC, with rates set on a combined cost-of-service basis.

In addition, the FERC regulates the SIA, Operating Agreement, TA and TCA, all of which allocate shared system costs and revenues among the utility subsidiaries that are parties to each agreement.  The FERC also regulates the PCA. See Note 14- Related Party Transactions for additional information.
Basis of Accounting

APCo’s accounting is subject to the requirements of the Virginia SCC, the WVPSC and the FERC. The financial statements have been prepared in accordance with the Uniform System of Accounts prescribed by the FERC. The principal differences from GAAP include:

·Accounting for subsidiaries on an equity basis.
·The classification of deferred fuel as noncurrent rather than current.
·The requirement to report deferred tax assets and liabilities separately rather than as a single amount.
·The classification of accrued taxes as a single amount rather than as assets and liabilities.
·The exclusion of current maturities of long-term debt from current liabilities.
·The classification of accrued non-ARO asset removal costs as accumulated depreciation rather than regulatory liabilities.
·The classification of finance lease payments as operating activities instead of financing activities.
·The classification of gains/losses from disposition of allowances as utility operating expenses rather than as operating revenues.
·The classification of PJM hourly activity for physical transactions as purchases and sales instead of net sales.
·The classification of regulatory assets and liabilities related to the accounting guidance for “Accounting for Income Taxes” as separate assets and liabilities rather than as a single amount.
·The presentation of finance leased assets and their associated accumulated amortization as a single amount instead of as separate amounts.
·The classification of factored accounts receivable expense as a nonoperating expense instead of as an operating expense.
·The classification of certain nonoperating revenues as miscellaneous nonoperating income instead of as operating revenue.
·The classification of certain nonoperating expenses as miscellaneous nonoperating expense instead of as operating expense.
·The separate classification of income tax expense for operating and nonoperating activities instead of as a single income tax expense.
·The classification of gas procurement sales as a reduction of fuel expense rather than as revenue.
·The classification of unamortized loss on reacquired debt in deferred debits rather than in regulatory assets.
·The classification of accumulated deferred investment tax credits in deferred credits rather than in regulatory liabilities and deferred investment tax credits.
·The classification of deferred equity income in other deferred credits rather than in other noncurrent assets as securitized transition assets.
·
The classification of amortization of deferred equity in operating revenues rather than in depreciation and
amortization.
·The classification of certain other assets and liabilities as current instead of noncurrent.
·The classification of certain other assets and liabilities as noncurrent instead of current.
·The classification of debt issuance costs as noncurrent assets instead of noncurrent liabilities.
·The classification of rents receivable as rents receivable instead of customer accounts receivable.
·
The classification of Non-Service Cost Components of Net Periodic Benefit Cost as Operating Expense
instead of Other Income (Expense).
·The classification of operating lease assets as Utility Plant rather than as a noncurrent asset.
·
The presentation of obligations under finance and operating leases as a single amount in Obligations Under
Capital Leases rather than as separate items.
·The classification of certain expenses in operating income rather than operating expenses.
·
The classification of interest on regulated finance leases as operating expense instead of Other Income
(Expense).
·The classification of certain write offs as depreciation expense rather than as operating expenses.
·The classification of cloud computing implementation costs as Utility Plant rather than as a noncurrent asset.
·The classification of accelerated depreciation caused by regulatory orders as accumulated depreciation than regulatory liabilities.
·The classification of deferred FICA taxes as taxes accrued rather than as a noncurrent liability.
·
The classification of expenses and revenues caused by regulatory orders as depreciation expense rather than
operating revenues.
·The classification of the amortization of certain regulatory assets as regulatory debits and credits rather than operating expenses.
Accounting for the Effects of Cost-Based Regulation

APCo’s financial statements reflect the actions of regulators that result in the recognition of certain revenues and expenses in different time periods than enterprises that are not rate-regulated.  In accordance with accounting guidance for “Regulated Operations,” regulatory assets (deferred expenses) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching income with its passage to customers in cost-based regulated rates.

Use of Estimates

The preparation of these financial statements requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes.  These estimates include, but are not limited to, inventory valuation, allowance for doubtful accounts, long-lived asset impairment, unbilled electricity revenue, valuation of long-term energy contracts, the effects of regulation, long-lived asset recovery, storm costs, the effects of contingencies and certain assumptions made in accounting for pension and postretirement benefits.  The estimates and assumptions used are based upon management’s evaluation of the relevant facts and circumstances as of the date of the financial statements.  Actual results could ultimately differ from those estimates.

Cash and Cash Equivalents

Cash and Cash Equivalents include Cash, Working Fund and Temporary Cash Investments on the balance sheets with original maturities of three months or less.

Supplementary Information
20212020
For the Years Ended December 31,(in millions)
Cash was Paid (Received) for:
Interest (Net of Capitalized Amounts)$207.5$207.1
Income Taxes (Net of Refunds)32.70.6
Noncash Acquisitions Under Finance Leases1.77.2
As of December 31,
Construction Expenditures Included in Current and Accrued Liabilities139.1105.6


Special Deposits

Special Deposits include funds held by trustees primarily for margin deposits for risk management activities.
Inventory

Fossil fuel and materials and supplies inventories are carried at average cost.

Accounts Receivable

Customer accounts receivable primarily include receivables from wholesale and retail energy customers, receivables from energy contract counterparties related to risk management activities and customer receivables primarily related to other revenue-generating activities.

Revenue is recognized over time as the performance obligations of delivering energy to customers are satisfied.  To the extent that deliveries have occurred but a bill has not been issued, APCo accrues and recognizes, as Accrued Utility Revenues on the balance sheets, an estimate of the revenues for energy delivered since the last billing.

AEP Credit factors accounts receivable on a daily basis, excluding receivables from risk management activities, through purchase agreements with APCo.  Since APCo does not have regulatory authority to sell accounts receivable in its West Virginia regulatory jurisdiction, only a portion of APCo’s accounts receivable are sold to AEP Credit.  AEP Credit has a receivables securitization agreement with bank conduits. Under the securitization agreement, AEP Credit receives financing from bank conduits for the interest in the billed and unbilled receivables they acquire from affiliated utility subsidiaries. See “Securitized Accounts Receivable – AEP Credit” section of Note 13 for additional information.

Allowance for Uncollectible Accounts

Generally, AEP Credit records bad debt expense based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable purchased from APCo. The assessment is performed by APCo which inherently contemplates any differences in geographical risk characteristics for the allowance. For receivables related to APCo’s West Virginia operations, the bad debt reserve is calculated based on a rolling two-year average write-off in proportion to gross accounts receivable. For customer accounts receivables relating to risk management activities, accounts receivables are reviewed for bad debt reserves at a specific counterparty level basis. For miscellaneous accounts receivable, bad debt expense is recorded based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable, unless specifically identified. In addition to these processes, management contemplates available current information, as well as any reasonable and supportable forecast information, to determine if allowances for uncollectible accounts should be further adjusted in accordance with the accounting guidance for “Credit Losses.” Management’s assessments contemplate expected losses over the life of the accounts receivable.

Concentrations of Credit Risk and Significant Customers

APCo does not have any significant customers that comprise 10% or more of its operating revenues.

APCo monitors credit levels and the financial condition of its customers on a continuous basis to minimize credit risk.  The regulatory commissions allow recovery in rates for a reasonable level of bad debt costs.  Management believes adequate provisions for credit loss have been made in the accompanying financial statements.

Property, Plant and Equipment

Electric utility property, plant and equipment for rate-regulated operations are stated at original cost. Additions, major replacements and betterments are added to the plant accounts.  Under the group composite method of depreciation, continuous interim routine replacements of items such as boiler tubes, pumps, motors, etc. result in original cost retirements, less salvage, being charged to accumulated depreciation.  The group composite method of
depreciation assumes that on average, asset components are retired at the end of their useful lives and thus there is no gain or loss.  The equipment in each primary electric plant account is identified as a separate group.  The depreciation rates that are established take into account the past history of interim capital replacements and the amount of removal cost incurred and salvage received.  These rates and the related lives are subject to periodic review.  Removal costs accrued are charged to accumulated depreciation. The costs of labor, materials and overhead incurred to operate and maintain plant and equipment are included in operating expenses.

Long-lived assets are required to be tested for impairment when it is determined that the carrying value of the assets may no longer be recoverable or when the assets meet the held-for-sale criteria under the accounting guidance for “Impairment or Disposal of Long-Lived Assets.”  When it becomes probable that an asset in-service or an asset under construction will be abandoned and regulatory cost recovery has been disallowed or is not probable, the cost of that asset shall be removed from plant-in-service or CWIP and charged to expense. The fair value of an asset is the amount at which that asset could be bought or sold in a current transaction between willing parties, as opposed to a forced or liquidation sale.  Quoted market prices in active markets are the best evidence of fair value and are used as the basis for the measurement, if available.  In the absence of quoted prices for identical or similar assets in active markets, fair value is estimated using various internal and external valuation methods including cash flow analysis and appraisals.

Subsidiary Companies

APCo has three wholly-owned coal company subsidiaries, Cedar Coal Company, Central Appalachian Coal Company and Southern Appalachian Coal Company and one jointly owned subsidiary, Central Coal Company. The coal companies were formerly engaged in coal-mining operations and currently lease and sublease portions of their coal rights and land to nonaffiliated companies. Investment in the net assets of the coal company subsidiaries is carried at cost plus equity in their undistributed earnings since acquisition.

Appalachian Consumer Rate Relief Funding LLC, a wholly-owned subsidiary of APCo, was formed for the purpose of issuing and servicing securitization bonds related to the under-recovered ENEC deferral balance and is consolidated in APCo’s financial statements.

Allowance for Funds Used During Construction

AFUDC represents the estimated cost of borrowed and equity funds used to finance construction projects that is capitalized and recovered through depreciation over the service life of regulated electric utility plant.

Valuation of Nonderivative Financial Instruments

The book values of Cash, Special Deposits, Working Fund, Notes Receivable from Associated Companies, Notes Payable to Associated Companies, accounts receivable and accounts payable approximate fair value because of the short-term maturity of these instruments.

Fair Value Measurements of Assets and Liabilities

The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement).  Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2.  When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value.  Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices
for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability.

For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1.  Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1.  Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated.  Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace.  When multiple broker quotes are obtained, the quoted bid and ask prices are averaged.  In certain circumstances, a broker quote may be discarded if it is a clear outlier.  Management uses a historical correlation analysis between the broker quoted location and the illiquid locations.  If the points are highly correlated, these locations are included within Level 2 as well.  Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information.  Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs.  Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value.  When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3.  The main driver of contracts being classified as Level 3 is the inability to substantiate energy price curves in the market.  A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility.

AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the benefit plan.  AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value.  AEP’s management performs its own valuation testing to verify the fair values of the securities.  AEP receives audit reports of the trustee’s operating controls and valuation processes.  

Assets in the benefit trusts are classified using the following methods.  Equities are classified as Level 1 holdings if they are actively traded on exchanges.  Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities.  They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets.  Items classified as Level 2 are primarily investments in individual fixed income securities.  Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data.  Pricing vendors calculate bond valuations using financial models and matrices.  The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation.  Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments.  Investments with unobservable valuation inputs are classified as Level 3 investments.  Investments classified as Other are valued using Net Asset Value as a practical expedient. Items classified as Other are primarily cash equivalent funds, common collective trusts, commingled funds, structured products, private equity, real estate, infrastructure and alternative credit investments. These investments do not have a readily determinable fair value or they contain redemption restrictions which may include the right to suspend redemptions under certain circumstances. Redemption restrictions may also prevent certain investments from being redeemed at the reporting date for the underlying value.

Deferred Fuel Costs

The cost of fuel and related emission allowances and emission control chemicals/consumables is charged to Operation Expenses when the fuel is burned or the allowance or consumable is utilized. Fuel cost over-recoveries (the excess of fuel-related revenues over applicable fuel costs incurred) are generally deferred as regulatory liabilities and under-recoveries (the excess of applicable fuel costs incurred over fuel-related revenues) are generally
deferred as regulatory assets.  These deferrals are amortized when refunded or when billed to customers in later months with the Virginia SCC’s and the WVPSC’s review and approval.  The amount of an over-recovery or under-recovery can also be affected by actions of the Virginia SCC and the WVPSC.  On a routine basis, the Virginia SCC and the WVPSC review and/or audit APCo’s fuel procurement policies and practices, the fuel cost calculations and FAC deferrals.  FAC deferrals are adjusted when costs are no longer probable of recovery or when refunds of fuel reserves are probable. APCo shares the majority of its Off-system Sales margins to customers either through an active FAC or other rate mechanisms. Where the FAC or Off-system Sales sharing mechanism is capped, frozen or non-existent, changes in fuel costs or sharing of off-system sales impact earnings.

Revenue Recognition

Regulatory Accounting

APCo’s financial statements reflect the actions of regulators that can result in the recognition of revenues and expenses in different time periods than enterprises that are not rate-regulated.  Regulatory assets (deferred expenses or alternative revenues recognized in accordance with the guidance for “Regulated Operations”) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching revenue with its passage to customers in cost-based regulated rates.

When regulatory assets are probable of recovery through regulated rates, assets are recorded on the balance sheets.  Regulatory assets are reviewed for probability of recovery at each balance sheet date or whenever new events occur.  Examples of new events include the issuance of a regulatory commission order or passage of new legislation.  If it is determined that recovery of a regulatory asset is no longer probable, the regulatory asset is derecognized as a charge against income.

Retail and Wholesale Supply and Delivery of Electricity

APCo recognizes revenues from customers for retail and wholesale electricity sales and electricity transmission and distribution delivery services.  APCo recognizes such revenues on the statements of income as the performance obligations of delivering energy to customers are satisfied. Recognized revenues include both billed and unbilled amounts.  

Wholesale transmission revenue is based on FERC-approved formula rate filings made for each calendar year using estimated costs. Revenues initially recognized per the annual rate filing are compared to actual costs, resulting in the subsequent recognition of an over or under-recovered amount, with interest, that is refunded or recovered, respectively, in a future year’s rates. These annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations”, and are recognized by APCo in the second quarter of each calendar year following the filing of annual FERC reports. Any portion of the true-ups applicable to an affiliated company is recorded as Accounts Receivable from Associated Companies or Accounts Payable to Associated Companies on the balance sheets. Any portion of the true-ups applicable to third-parties is recorded as regulatory assets or regulatory liabilities on the balance sheets. See Note 16 - Revenue from Contracts with Customers for additional information.

Gross versus Net Presentation of Certain Electricity Supply and Delivery Activities

Most of the power produced at the generation plants is sold to PJM.  APCo also purchases power from PJM to supply power to customers.  Generally, these power sales and purchases are reported on a net basis as revenues on the statements of income.  However, purchases of power in excess of sales to PJM, on an hourly net basis, used to serve retail load are recorded gross as Operation Expenses on the statements of income.
Physical energy purchases arising from non-derivative contracts are accounted for on a gross basis in Operation Expenses on the statements of income.  Energy purchases arising from non-trading derivative contracts are recorded based on the transaction’s facts and circumstances.  Purchases under non-trading derivatives used to serve accrual based obligations are recorded in Operation Expenses on the statements of income.  All other non-trading derivative purchases are recorded net in revenues.

In general, APCo records expenses when purchased electricity is received and when expenses are incurred. APCo defers unrealized MTM amounts as regulatory assets (for losses) and regulatory liabilities (for gains).

Energy Marketing and Risk Management Activities

APCo engages in power, capacity and, to a lesser extent, natural gas marketing as a major power producer and participant in electricity and natural gas markets. APCo also engages in power, capacity, coal, natural gas and, to a lesser extent, heating oil, gasoline and other commodity risk management activities focused on markets where the AEP System owns assets and on adjacent markets. These activities include the purchase-and-sale of energy under forward contracts at fixed and variable prices. These contracts include physical transactions, exchange-traded futures, and to a lesser extent, OTC swaps and options. Certain energy marketing and risk management transactions are with RTOs.

APCo recognizes revenues from marketing and risk management transactions that are not derivatives as the performance obligation of delivering the commodity is satisfied. Expenses from marketing and risk management activities that are not derivatives are also recognized upon delivery of the commodity.

APCo uses MTM accounting for marketing and risk management transactions that are derivatives unless the derivative is designated in a qualifying cash flow hedge relationship or elected normal under the normal purchase normal sale election. Unrealized MTM gains and losses are included on APCo balance sheets as Derivative Instrument Assets or Liabilities, as appropriate, and on the statements of income in Operating Revenues. Realized gains and losses on marketing and risk management transactions are included in revenues or expenses based on the transaction’s facts and circumstances. However, in regulated jurisdictions subject to cost-based regulation, unrealized MTM amounts and some realized gains and losses are deferred as regulatory assets (for losses) and regulatory liabilities (for gains).

Certain qualifying marketing and risk management derivatives transactions are designated as hedges of variability in future cash flows as a result of forecasted transactions (cash flow hedge). In the event APCo designates a cash flow hedge, the cash flow hedge’s gain or loss is initially recorded as a component of AOCI. When the forecasted transaction is realized and affects net income, APCo subsequently reclassifies the gain or loss on the hedge from AOCI into revenues or expenses within the same financial statement line item as the forecasted transaction on their statements of income. See “Accounting for Cash Flow Hedging Strategies” section of Note 10 for additional information.

Maintenance

APCo expenses maintenance costs as incurred.  If it becomes probable that APCo will recover specifically-incurred costs through future rates, a regulatory asset is established to match the expensing of those maintenance costs with
its recovery in cost-based regulated revenues.  APCo defers costs above the level included in base rates and amortizes those deferrals commensurate with recovery through rate riders.

Income Taxes and Investment Tax Credits

APCo uses the liability method of accounting for income taxes.  Under the liability method, deferred income taxes are provided for all temporary differences between the book and tax basis of assets and liabilities which will result
in a future tax consequence. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled.

When the flow-through method of accounting for temporary differences is required by a regulator to be reflected in regulated revenues (that is, when deferred taxes are not included in the cost-of-service for determining regulated rates for electricity), deferred income taxes are recorded and related regulatory assets and liabilities are established to match the regulated revenues and tax expense.

APCo applies the deferral methodology for the recognition of ITCs. Deferred ITCs are amortized to income tax expense over the life of the asset that generated the credit. Amortization of deferred ITCs begins when the asset is placed in-service, except where regulatory commissions reflect ITCs in the rate-making process, then amortization begins when the cash tax benefit is recognized.

APCo accounts for uncertain tax positions in accordance with the accounting guidance for “Income Taxes.”  APCo classifies interest expense or income related to uncertain tax positions as interest expense or income as appropriate and classifies penalties as Penalties on the statements of income.

Excise Taxes

As an agent for some state and local governments, APCo collects from customers certain excise taxes levied by those state or local governments on customers.  APCo does not record these taxes as revenue or expense.

Debt

Gains and losses from the reacquisition of debt used to finance regulated electric utility plants are deferred and amortized over the remaining term of the reacquired debt in accordance with their rate-making treatment unless the debt is refinanced.  If the reacquired debt associated with the regulated business is refinanced, the reacquisition costs attributable to the portions of the business that are subject to cost-based regulatory accounting are generally deferred and amortized over the term of the replacement debt consistent with its recovery in rates.

Debt discount or premium and debt issuance expenses are deferred and amortized generally utilizing the straight-line method over the term of the related debt.  The straight-line method approximates the effective interest method and is consistent with the treatment in rates for regulated operations.

Pension and OPEB Plans

APCo participates in an AEP sponsored qualified pension plan and an unfunded nonqualified pension plan. Substantially all APCo’s employees are covered by the qualified plan or both the qualified and a nonqualified pension plan. APCo also participates in OPEB plans sponsored by AEP to provide health and life insurance benefits for retired employees. APCo is allocated a proportionate share of benefit costs and account for their participation in these plans as multiple-employer plans. See Note 7 - Benefit Plans for additional information including significant accounting policies associated with the plans.

Investments Held in Trust for Future Liabilities

AEP has several trust funds with significant investments intended to provide for future payments of pension and OPEB benefits.  All of the trust funds’ investments are diversified and managed in compliance with all laws and regulations.  The investment strategy for the trust funds is to use a diversified portfolio of investments to achieve an acceptable rate of return while managing the investment risk of the assets relative to the associated liabilities.  To minimize investment risk, the trust funds are broadly diversified among classes of assets, investment strategies and investment managers.  Management regularly reviews the actual asset allocations and periodically rebalances the investments to targeted allocations when appropriate.  Investment policies and guidelines allow investment
managers in approved strategies to use financial derivatives to obtain or manage market exposures and to hedge assets and liabilities.  The investments are reported at fair value under the “Fair Value Measurements and Disclosures” accounting guidance.

Benefit Plans

All benefit plan assets are invested in accordance with each plan’s investment policy.  The investment policy outlines the investment objectives, strategies and target asset allocations by plan.

The investment philosophies for AEP’s benefit plans support the allocation of assets to minimize risks and optimize net returns.  Strategies used include:

Maintaining a long-term investment horizon.
Diversifying assets to help control volatility of returns at acceptable levels.
Managing fees, transaction costs and tax liabilities to maximize investment earnings.
Using active management of investments where appropriate risk/return opportunities exist.
Keeping portfolio structure style-neutral to limit volatility compared to applicable benchmarks.
Using alternative asset classes such as real estate and private equity to maximize return and provide additional portfolio diversification.

The objective of the investment policy for the pension fund is to maintain the funded status of the plan while providing for growth in the plan assets to offset the growth in the plan liabilities.  The current target asset allocations are as follows:
Pension Plan AssetsTarget
Equity25 %
Fixed Income59 %
Other Investments15 %
Cash and Cash Equivalents%
OPEB Plans AssetsTarget
Equity59 %
Fixed Income40 %
Cash and Cash Equivalents%

The investment policy for each benefit plan contains various investment limitations.  The investment policies establish concentration limits for securities and prohibit the purchase of securities issued by AEP (with the exception of proportionate and immaterial holdings of AEP securities in passive index strategies or certain commingled funds).  However, the investment policies do not preclude the benefit trust funds from receiving contributions in the form of AEP securities, provided that the AEP securities acquired by each plan may not exceed the limitations imposed by law.

For equity investments, the concentration limits are generally as follows:

No security in excess of 5% of all equities.
Cash equivalents must be less than 10% of an investment manager’s equity portfolio.
No individual stock may be more than 10% and 7% for pension and OPEB investments, respectively, of each manager’s equity portfolio.
No securities may be bought or sold on margin or other use of leverage.
For fixed income investments, each investment manager’s portfolio is compared to investment grade, diversified long and intermediate benchmark indices.

A portion of the pension assets is invested in real estate funds to provide diversification, add return and hedge against inflation.  Real estate properties are illiquid, difficult to value and not actively traded.  The pension plan uses external real estate investment managers to invest in commingled funds that hold real estate properties.  To mitigate investment risk in the real estate portfolio, commingled real estate funds are used to ensure that holdings are diversified by region, property type and risk classification.  Real estate holdings include core, value-added and opportunistic classifications.

A portion of the pension assets is invested in private equity.  Private equity investments add return and provide diversification and typically require a long-term time horizon to evaluate investment performance.  Private equity is classified as an alternative investment because it is illiquid, difficult to value and not actively traded.  The pension plan uses limited partnerships to invest across the private equity investment spectrum.   The private equity holdings are with multiple general partners who help monitor the investments and provide investment selection expertise.  The holdings are currently comprised of venture capital, buyout and hybrid debt and equity investments.  

AEP participates in a securities lending program with BNY Mellon to provide incremental income on idle assets and to provide income to offset custody fees and other administrative expenses.  AEP lends securities to borrowers approved by BNY Mellon in exchange for collateral.  All loans are collateralized by at least 102% of the loaned asset’s market value and the collateral is invested.  The difference between the rebate owed to the borrower and the collateral rate of return determines the earnings on the loaned security.  The securities lending program’s objective is to provide modest incremental income with a limited increase in risk. As of December 31, 2021 and 2020, the fair value of securities on loan as part of the program was $137 million and $177 million, respectively. Cash and securities obtained as collateral exceeded the fair value of the securities loaned as of December 31, 2021 and 2020.

Trust owned life insurance (TOLI) underwritten by The Prudential Insurance Company is held in the OPEB plan trusts.  The strategy for holding life insurance contracts in the taxable Voluntary Employees’ Beneficiary Association trust is to minimize taxes paid on the asset growth in the trust.  Earnings on plan assets are tax-deferred within the TOLI contract and can be tax-free if held until claims are paid.  Life insurance proceeds remain in the trust and are used to fund future retiree medical benefit liabilities.  With consideration to other investments held in the trust, the cash value of the TOLI contracts is invested in two diversified funds.  A portion is invested in a commingled fund with underlying investments in stocks that are actively traded on major international equity exchanges.  The other portion of the TOLI cash value is invested in a diversified, commingled fixed income fund with underlying investments in government bonds, corporate bonds and asset-backed securities.

Cash and cash equivalents are held in each trust to provide liquidity and meet short-term cash needs. Cash equivalent funds are used to provide diversification and preserve principal.  The underlying holdings in the cash funds are investment grade money market instruments including commercial paper, certificates of deposit, treasury bills and other types of investment grade short-term debt securities.  The cash funds are valued each business day and provide daily liquidity.





Comprehensive Income (Loss)
Comprehensive income (loss) is defined as the change in equity (net assets) of a business enterprise during a period from transactions and other events and circumstances from non-owner sources. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners.

Subsequent Events

Management has evaluated the impact of events occurring after December 31, 2021 through February 24, 2022, the date that AEP’s Form 10-K was issued, and has updated such evaluation for disclosure purposes through April 14, 2022. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.
2. NEW ACCOUNTING STANDARDS

During the FASB’s standard-setting process and upon issuance of final standards, management reviews the new accounting literature to determine its relevance, if any, to APCo’s business. There are no new standards expected to have a material impact on APCo’s financial statements.
3.  COMPREHENSIVE INCOME

Presentation of Comprehensive Income

The following tables provide the components of changes in AOCI and details of reclassifications from AOCI for the years ended December 31, 2021 and 2020.  The amortization of pension and OPEB AOCI components are included in the computation of net periodic pension and OPEB costs. See Note 7 - Benefit Plans for additional information.
Pension and OPEB 
AmortizationChanges in
Cash Flow Hedge –of DeferredFunded
For the Year Ended December 31, 2021Interest RateCostsStatusTotal
(in millions)
Balance in AOCI as of December 31, 2020$(0.8)$5.4 $2.6 $7.2 
Change in Fair Value Recognized in AOCI
9.2 — 13.1 22.3 
Amount of (Gain) Loss Reclassified from AOCI
Interest on Long-Term Debt (a)(1.1)— — (1.1)
Amortization of Prior Service Cost (Credit)— (5.3)— (5.3)
Reclassifications from AOCI, before Income Tax (Expense) Benefit
(1.1)(5.3)— (6.4)
Income Tax (Expense) Benefit(0.2)(1.1)— (1.3)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit
(0.9)(4.2)— (5.1)
Net Current Period Other Comprehensive Income (Loss)8.3 (4.2)13.1 17.2 
Balance in AOCI as of December 31, 2021$7.5 $1.2 $15.7 $24.4 

Pension and OPEB
AmortizationChanges in
Cash Flow Hedges -of DeferredFunded
For the Year Ended December 31, 2020Interest RateCostsStatusTotal
(in millions)
Balance in AOCI as of December 31, 2019$0.9 $9.2 $(5.1)$5.0 
Change in Fair Value Recognized in AOCI
(0.7)— 8.4 7.7 
Amount of (Gain) Loss Reclassified from AOCI
Interest on Long-Term Debt (a)(1.3)— — (1.3)
Amortization of Prior Service Cost (Credit)— (5.3)— (5.3)
Amortization of Actuarial (Gains) Losses— 0.5 — 0.5 
Reclassifications from AOCI, before Income Tax (Expense) Benefit
(1.3)(4.8)— (6.1)
Income Tax (Expense) Benefit(0.3)(1.0)— (1.3)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit
(1.0)(3.8)— (4.8)
Net Current Period Other Comprehensive Income (Loss)(1.7)(3.8)8.4 2.9 
Balance in AOCI as of December 31, 2020$(0.8)$5.4 $3.3 $7.9 

(a)Amounts reclassified to the referenced line item on the statements of income.
4.  RATE MATTERS

APCo is involved in rate and regulatory proceedings at the FERC and the Virginia SCC and the WVPSC. Rate matters can have a material impact on net income, cash flows and possibly financial condition. APCo’s recent significant rate orders and pending rate filings are addressed in this note.

2017-2019 Virginia Triennial Review

In November 2020, the Virginia SCC issued an order on APCo’s 2017-2019 Triennial Review filing concluding that APCo earned above its authorized ROE but within its ROE band for the 2017-2019 period, resulting in no refund to customers and no change to APCo base rates on a prospective basis. The Virginia SCC approved a prospective 9.2% ROE for APCo's 2020-2022 triennial review period with the continuation of a 140 basis point band (8.5% bottom, 9.2% midpoint, 9.9% top).

In December 2020, an intervenor filed a petition at the Virginia SCC requesting reconsideration of: (a) the failure of the Virginia SCC to apply a threshold earnings test to the approved regulatory asset for APCo’s closed coal-fired generation assets, (b) the Virginia SCC’s use of a 2011 benchmark study to measure the replacement value of capacity for purposes of APCo’s 2017 – 2019 earnings test and (c) the reasonableness and prudency of APCo’s investments in AMI meters.

In December 2020, APCo filed a petition at the Virginia SCC requesting reconsideration of: (a) certain issues related to APCo’s going-forward rates and (b) the Virginia SCC’s decision to deny APCo tariff changes that align rates with underlying costs. For APCo’s going-forward rates, APCo requested that the Virginia SCC clarify its final order and clarify whether APCo’s current rates will allow it to earn a fair return. If the Virginia SCC’s order did conclude on APCo’s ability to earn a fair return through existing base rates, APCo further requested that the Virginia SCC clarify whether it has the authority to also permit an increase in base rates.

In March 2021, an intervenor filed its assignments of error with the Virginia Supreme Court related to the appeal of the November 2020 order in which it stated the Virginia SCC erred: (a) in determining that Virginia law did not apply to its determination to permit amortization for recovery of costs associated with retired coal-fired generation assets, (b) in establishing a new regulatory asset for a cost incurred outside of the triennial review period due to its failure to apply a threshold earnings test before approving deferred cost recovery and (c) in misapplying the requirement that APCo bear the burden of demonstrating that power purchases made by APCo from its affiliate, OVEC, were priced at the lower of OVEC’s cost or the market price for nonaffiliated power.

In March 2021, APCo filed its assignments of error with the Virginia Supreme Court related to its appeal of the November 2020 order in which it stated the Virginia SCC erred: (a) in finding that costs associated with asset impairments related to early retirement determinations made by APCo for certain generation facilities should not be attributed to the test periods under review and deemed fully recovered in the period recorded, (b) in finding that it was permitted to evaluate the reasonableness of APCo’s decision to record, per books for financial reporting purposes, asset impairments related to early retirement determinations for certain generation facilities, (c) as a result of the errors described in (a) and (b), in denying APCo an increase in rates, (d) in failing to review and make any findings regarding whether APCo’s rates would allow it to earn a fair rate of return going forward, (e) in denying APCo an increase in base rates by failing to ensure that APCo has an opportunity to recover its costs and earn a fair rate of return, thereby resulting in a taking of private property for public use without just compensation and (f) in retroactively adjusting APCo’s depreciation expense for purposes of calculating APCo’s earnings for the 2017-2019 triennial period.

In March 2021, the Virginia SCC issued an order confirming certain of its decisions from the November 2020 order and rejecting the various requests for reconsideration from APCo and an intervenor. In confirming its decision to reject an intervenor’s recommendation that APCo’s AMI costs incurred during the triennial period be disallowed,
the Virginia SCC clarified that APCo established the need to replace its existing AMR meters, and that based on the uncertainty surrounding the continued manufacturing and support of AMR technology, APCo reasonably chose to replace them with AMI meters. In March 2021, APCo filed a notice of appeal of the reconsideration order with the Virginia Supreme Court. In September 2021, APCo submitted its brief before the Virginia Supreme Court. The brief was in alignment with the assignments of error filed by APCo in March 2021. In October 2021, the Virginia SCC and additional intervenors filed briefs with the Virginia Supreme Court disagreeing with APCo’s assignments of error in its appeal of the Triennial Review decision. Additionally, the Virginia SCC and APCo filed briefs disagreeing with an intervenor’s assignments of error in a separate appeal of the same decision. Oral arguments are scheduled to be held at the Virginia Supreme Court in March 2022.

APCo ultimately seeks an increase in base rates through its appeal to the Virginia Supreme Court. Among other issues, this appeal includes APCo’s request for proper treatment of the closed coal-fired plant assets in APCo’s 2017-2019 triennial period, reducing APCo’s earnings below the bottom of its authorized ROE band. If APCo’s appeals regarding treatment of the closed coal plants are granted by the Virginia Supreme Court, it could initially reduce future net income and impact financial condition. A Virginia Supreme Court decision in favor of APCo’s original expensing of the closed coal-fired plant asset balances would likely result in a remand to the Virginia SCC. Upon a subsequent Virginia SCC order, the initial negative impact for the write-off of the closed coal-fired plant asset balances could potentially be offset by an increase in base rates for earning below APCo’s 2017-2019 authorized ROE band.

CCR/ELG Compliance Plan Filings

In December 2020, APCo submitted filings with the Virginia SCC and WVPSC requesting approvals necessary to implement CCR/ELG compliance plans at the Amos and Mountaineer Plants. Intervenors in Virginia and West Virginia recommended that only the CCR-related investments be constructed at Amos and Mountaineer and, as a consequence, that APCo close these generating facilities at the end of 2028.

In August 2021, the Virginia SCC issued an order approving APCo’s request to construct CCR-related investments at the Amos and Mountaineer Plants and approved recovery of CCR-related other operation and maintenance expenses and investments through an active rider. The order denied APCo’s request to construct the ELG investments and denied recovery of previously incurred ELG costs. APCo plans to refile for approval of the ELG investments and previously incurred ELG costs in the first quarter of 2022.

Also in August 2021, the WVPSC approved the request to construct CCR/ELG investments at the Amos and Mountaineer Plants and approved recovery of the West Virginia jurisdictional share of these costs through an active rider. In October 2021, due to the Virginia SCC previously rejecting the ELG investments, the WVPSC issued an order directing APCo to proceed with CCR/ELG compliance plans that would allow the plants to continue operating beyond 2028. The October order further states that APCo will not share capacity and energy from the plants with customers from Virginia if those customers are not paying for ELG compliance costs, or for any new capital investment or continuing operations costs incurred, to allow the plants to operate beyond 2028 or prevent downgrades prior to 2028. The WVPSC also ordered that APCo will be given the opportunity to recover, from West Virginia customers, the new capital and operating costs arising solely from the WVPSC's directive to operate the plants beyond 2028 if the WVPSC finds that the costs are reasonably and prudently incurred. In October and November 2021, intervenors filed petitions for reconsideration at the WVPSC requesting clarification on certain aspects of the order, primarily the jurisdictional allocation of future operating expenses and plant costs.

APCo expects total Amos and Mountaineer Plant ELG investment, excluding AFUDC, to be approximately $197 million. As of December 31, 2021, APCo’s Virginia jurisdictional share of the net book value, before cost of removal including CWIP and inventory, of the Amos and Mountaineer Plants was approximately $1.5 billion and APCo’s Virginia jurisdictional share of its ELG investment balance in CWIP for these plants was $26 million.
If any of the ELG costs are not approved for recovery and/or the retirement dates of the Amos and Mountaineer plants are accelerated to 2028 without commensurate cost recovery, it would reduce future net income and cash flows and impact financial condition.

Fuel Adjustment Clause

The Division of Audits and Accounting in the the FERC is commencing an audit of APCo. The audit will evaluate APCo’s compliance with: (1) its Commission-approved fuel-adjustment clauses and formula rate or tariff recovery mechanisms used to recover fuel and purchased-power costs in billings to wholesale customers; and (2) accounting regulations in the Uniform System of Accounts for public utilities related to fuel and purchased-power costs. The audit will cover the period from January 1, 2019 to the present.
5.  EFFECTS OF REGULATION

Regulatory Assets and Liabilities

Regulatory assets and liabilities are comprised of the following items:
December 31,
Remaining
Recovery
Period
Regulatory Assets:20212020
(in millions)
Regulatory assets pending final regulatory approval:
Regulatory Assets Currently Earning a Return
COVID-19 - Virginia$6.8 $3.7 
Total Regulatory Assets Currently Earning a Return6.8 3.7 
Regulatory Assets Currently Not Earning a Return
Storm-Related Costs68.8 3.5 
Plant Retirement Costs - Asset Retirement Obligation Costs25.9 29.8 
Environmental Expense Deferral - Virginia— 9.3 
Other Regulatory Assets Pending Final Regulatory Approval3.6 1.5 
Total Regulatory Assets Currently Not Earning a Return98.3 44.1 
Total Regulatory Assets Pending Final Regulatory Approval105.1 47.8 
Regulatory assets approved for recovery:
Regulatory Assets Currently Earning a Return
Under-recovered Fuel Costs - Virginia127.2 3.3 1 year
Plant Retirement Costs - Unrecovered Plant30.9 40.0 22 years
Other Regulatory Assets Approved for Recovery0.4 1.0 various
Total Regulatory Assets Currently Earning a Return158.5 44.3 
Regulatory Assets Currently Not Earning a Return
Income Tax Assets327.9 356.4 
Plant Retirement Costs - Asset Retirement Obligation Costs293.1 198.8 15 years
Under-recovered Fuel Costs74.1 2.0 1 year
Pension and OPEB Funded Status62.7 114.4 12 years
Virginia Transmission Rate Adjustment Clause37.2 18.8 2 years
Peak Demand Reduction/Energy Efficiency17.8 16.8 5 years
Environmental Compliance Costs13.7 — 2 years
Postemployment Benefits13.3 13.5 3 years
Vegetation Management Program - West Virginia11.9 45.4 2 years
PJM Annual Formula Rate True-up3.5 12.7 2 years
Other Regulatory Assets Approved for Recovery10.6 12.7 various
Total Regulatory Assets Currently Not Earning a Return865.8 791.5 
Total Regulatory Assets Approved for Recovery1,024.3 835.8 
Total FERC Account 182.3 Regulatory Assets$1,129.4 $883.6 
December 31,
Remaining
Refund
Period
Regulatory Liabilities:20212020
(in millions)
Regulatory liabilities Pending Final Regulatory Determination
Income Tax Related Regulatory Liabilities (a)
Excess ADIT that is Not Subject to Rate Normalization Requirements (b)$4.5 $— 
Total Regulatory Liabilities Pending Final Regulatory Determination4.5 — 
Regulatory liabilities approved for payment
Regulatory Liabilities Currently Not Paying a Return
Unrealized Gain on Forward Commitments$28.2 $5.5 3 years
PJM Transmission Enhancement Refund13.0 16.3 4 years
Other Regulatory Liabilities Approved for Payment15.0 6.9 various
Total Regulatory Liabilities Currently Not Paying a Return56.2 28.7 
Income Tax Related Regulatory Liabilities (a)
Excess ADIT Associated with Certain Depreciable Property663.6 690.0 (c)
Excess ADIT that is Not Subject to Rate Normalization Requirements83.6 139.1 7 years
Income Taxes Subject to Flow Through13.6 — 23 years
Total Income Tax Related Regulatory Liabilities760.8 829.1 
Total Regulatory Liabilities Approved for Payment817.0 857.8 
Total FERC 254 Account Regulatory Liabilities$821.5 $857.8 

(a)Predominately pays a return due to the inclusion of Excess ADIT in rate base.
(b)Amount represents regulatory liabilities for Excess ADIT as a result of a change in the state income tax apportionment formula in West Virginia. See the “Federal and State Tax Legislation” section of Note 11 for additional information.
(c)Refunded using ARAM.
6.  COMMITMENTS, GUARANTEES AND CONTINGENCIES

APCo is subject to certain claims and legal actions arising in the ordinary course of business.  In addition, APCo’s business activities are subject to extensive governmental regulation related to public health and the environment.  The ultimate outcome of such pending or potential litigation cannot be predicted.  Management accrues contingent liabilities only when management concludes that it is both probable that a liability has been incurred at the date of the financial statements and the amount of loss can be reasonably estimated. When management determines that it is not probable, but rather reasonably possible that a liability has been incurred at the date of the financial statements, management discloses such contingencies and the possible loss or range of loss if such estimate can be made. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the maximum possible loss exposure. Circumstances change over time and actual results may vary significantly from estimates.

For current proceedings not specifically discussed below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the financial statements.

COMMITMENTS

APCo has substantial commitments for fuel, energy and capacity contracts as part of the normal course of business. Certain contracts contain penalty provisions for early termination.

In accordance with the accounting guidance for “Commitments”, the following table summarizes APCo’s actual contractual commitments as of December 31, 2021:

Contractual Commitments
Less Than
1 Year
2-3 Years4-5 Years
After
5 Years
Total
(in millions)
Fuel Purchase Contracts (a)(b)$266.9 $171.8 $18.7 $18.4 $475.8 
Energy and Capacity Purchase Contracts40.4 81.8 80.4 150.0 352.6 
Total$307.3 $253.6 $99.1 $168.4 $828.4 


(a)Represents contractual commitments to purchase coal, natural gas and other consumables as fuel for electric generation along with related transportation of the fuel.
(b)In the first quarter of 2022, APCo entered into new fuel purchase contracts related to coal procurement. The new commitments were as follows: $95 million in less than 1 year, $449 million in 2-3 years and $96 million in 4-5 years. These commitments are not included in the tables above. All other new commitments in the first quarter of 2022 were immaterial.

GUARANTEES

Liabilities for guarantees are recorded in accordance with the accounting guidance for “Guarantees.”  There is no collateral held in relation to any guarantees.  In the event any guarantee is drawn, there is no recourse to third-parties unless specified below.

Indemnifications and Other Guarantees

Contracts

APCo enters into certain types of contracts which require indemnifications.  Typically these contracts include, but are not limited to, sale agreements, lease agreements, purchase agreements and financing agreements.  Generally, these agreements may include, but are not limited to, indemnifications around certain tax, contractual and
environmental matters.  With respect to sale agreements, exposure generally does not exceed the sale price.  As of December 31, 2021, there were no material liabilities recorded for any indemnifications.

AEPSC conducts power purchase-and-sale activity on behalf of APCo, I&M, KPCo and WPCo, who are jointly and severally liable for activity conducted on their behalf.  

Lease Obligations

APCo leases equipment under master lease agreements.  See “Master Lease Agreements” section of Note 12 for additional information.

ENVIRONMENTAL CONTINGENCIES

The Comprehensive Environmental Response Compensation and Liability Act (Superfund) and State Remediation

By-products from the generation of electricity include materials such as ash, slag and sludge.  Coal combustion by-products, which constitute the overwhelming percentage of these materials, are typically treated and deposited in captive disposal facilities or are beneficially utilized.  In addition, the generation plants and transmission and distribution facilities have used asbestos, polychlorinated biphenyls and other hazardous and non-hazardous materials.  APCo currently incurs costs to dispose of these substances safely.

Superfund addresses clean-up of hazardous substances that are released to the environment.  The Federal EPA administers the clean-up programs.  Several states enacted similar laws.  As of December 31, 2021, APCo was named as a Potentially Responsible Party (PRP) for one site by the Federal EPA for which alleged liability is unresolved.  There are 2 additional sites for which APCo received information requests which could lead to PRP designation.  In those instances where a PRP or defendant has been named, disposal or recycling activities were in accordance with the then-applicable laws and regulations. Superfund does not recognize compliance as a defense, but imposes strict liability on parties who fall within its broad statutory categories.  Liability has been resolved for a number of sites with no significant effect on net income.

Management evaluates the potential liability for each Superfund site separately, but several general statements can be made about potential future liability.  Allegations that materials were disposed at a particular site are often unsubstantiated and the quantity of materials deposited at a site can be small and often non-hazardous.  Although Superfund liability has been interpreted by the courts as joint and several, typically many parties are named as PRPs for each site and several of the parties are financially sound enterprises.  As of December 31, 2021, management’s estimates do not anticipate material clean-up costs for identified Superfund sites.

OPERATIONAL CONTINGENCIES

Insurance and Potential Losses

APCo maintains insurance coverage normal and customary for electric utilities, subject to various deductibles.  APCo also maintains property and casualty insurance that may cover certain physical damage or third-party injuries caused by cyber security incidents. Insurance coverage includes all risks of physical loss or damage to nonnuclear assets, subject to insurance policy conditions and exclusions.  Covered property generally includes power plants, substations, facilities and inventories.  Excluded property generally includes transmission and distribution lines, poles and towers.  The insurance programs also generally provide coverage against loss arising from certain claims made by third-parties and are in excess of retentions absorbed by APCo.  Coverage is generally provided by a combination of the protected cell of EIS and/or various industry mutual and/or commercial insurance carriers.
Some potential losses or liabilities may not be insurable or the amount of insurance carried may not be sufficient to meet potential losses and liabilities, including, but not limited to, liabilities relating to a cyber security incident.  Future losses or liabilities, if they occur, which are not completely insured, unless recovered from customers, could reduce future net income and cash flows and impact financial condition.

Claims Challenging Transition of American Electric Power System Retirement Plan to Cash Balance Formula 

Four participants in The American Electric Power System Retirement Plan (the Plan) filed a class action complaint in December 2021 in the U.S. District Court for the Southern District of Ohio against AEPSC and the Plan. When the Plan’s benefit formula was changed in the year 2000, AEP provided a special provision for employees hired before January 1, 2001, allowing them to continue benefit accruals under the then benefit formula for a full 10 years alongside of the new cash balance benefit formula then being implemented. Employees who were hired on or after January 1, 2001 accrued benefits only under the new cash balance benefit formula. The Plaintiffs assert a number of claims on behalf of themselves and the purported class, including that: (a) the Plan violates the requirements under the Employee Retirement Income Security Act (ERISA) intended to preclude back-loading the accrual of benefits to the end of a participant’s career, (b) the Plan violates the age discrimination prohibitions of ERISA and the Age Discrimination in Employment Act and (c) AEP failed to provide required notice regarding the changes to the Plan. Among other relief, the Complaint seeks reformation of the Plan to provide additional benefits and the recovery of plan benefits for former employees under such reformed plan. The Plaintiffs previously had submitted claims for additional plan benefits to AEP, which were denied. On February 15, 2022, AEPSC and the Plan filed a motion to dismiss the complaint for failure to state a claim. AEP will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring.
7.  BENEFIT PLANS

For a discussion of investment strategy, investment limitations, target asset allocations and the classification of investments within the fair value hierarchy, see “Fair Value Measurements of Assets and Liabilities” and “Investments Held in Trust for Future Liabilities” sections of Note 1.

APCo participates in an AEP sponsored qualified pension plan and an unfunded nonqualified pension plan. Substantially all employees are covered by the qualified plan or both the qualified and a nonqualified pension plan. APCo also participates in OPEB plans sponsored by AEP to provide health and life insurance benefits for retired employees.

APCo recognizes the funded status associated with defined benefit pension and OPEB plans on the balance sheets.  Disclosures about the plans are required by the “Compensation – Retirement Benefits” accounting guidance.  APCo recognizes an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognizes, as a component of other comprehensive income, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost.  APCo records a regulatory asset instead of other comprehensive income for qualifying benefit costs of regulated operations that for rate-making purposes are deferred for future recovery.  The cumulative funded status adjustment is equal to the remaining unrecognized deferrals for unamortized actuarial losses or gains, prior service costs and transition obligations, such that remaining deferred costs result in an AOCI equity reduction or regulatory asset and deferred gains result in an AOCI equity addition or regulatory liability.

Actuarial Assumptions for Benefit Obligations

The weighted-average assumptions used in the measurement of benefit obligations are shown in the following table:
Pension PlansOPEB
December 31,
Assumption2021202020212020
Discount Rate2.90 %2.50 %2.90 %2.55 %
Interest Crediting Rate4.00 %4.00 %NANA
Rate of Compensation Increase4.85 %(a)4.85 %(a)NANA

(a)Rates are for base pay only.  In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees.
NA    Not applicable.

A duration-based method is used to determine the discount rate for the plans.  A hypothetical portfolio of high quality corporate bonds is constructed with cash flows matching the benefit plan liability.  The composite yield on the hypothetical bond portfolio is used as the discount rate for the plan.

For 2021, the rate of compensation increase assumed varies with the age of the employee, ranging from 3% per year to 11.5% per year, with the average increase shown in the table above.
Actuarial Assumptions for Net Periodic Benefit Costs

The weighted-average assumptions used in the measurement of benefit costs are shown in the following table:
Pension PlansOPEB
Year Ended December 31,
Assumption2021202020212020
Discount Rate2.50 %3.25 %2.55 %3.30 %
Interest Crediting Rate4.00 %4.00 %NANA
Expected Return on Plan Assets4.75 %5.75 %4.75 %5.50 %
Rate of Compensation Increase4.85 %(a)4.85 %(a)NANA
(a)Rates are for base pay only.  In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees.
NA Not applicable.
The expected return on plan assets was determined by evaluating historical returns, the current investment climate (yield on fixed income securities and other recent investment market indicators), rate of inflation, third-party forecasts and current prospects for economic growth.  

The health care trend rate assumptions used for OPEB plans measurement purposes are shown below:
December 31,
Health Care Trend Rates20212020
Initial6.25 %6.50 %
Ultimate4.50 %4.50 %
Year Ultimate Reached20292029
Significant Concentrations of Risk within Plan Assets

In addition to establishing the target asset allocation of plan assets, the investment policy also places restrictions on securities to limit significant concentrations within plan assets.  The investment policy establishes guidelines that govern maximum market exposure, security restrictions, prohibited asset classes, prohibited types of transactions, minimum credit quality, average portfolio credit quality, portfolio duration and concentration limits.  The guidelines were established to mitigate the risk of loss due to significant concentrations in any investment.  Management monitors the plans to control security diversification and ensure compliance with the investment policy.  As of December 31, 2021, the assets were invested in compliance with all investment limits.  See “Investments Held in Trust for Future Liabilities” section of Note 1 for limit details.

Benefit Plan Obligations, Plan Assets, Funded Status and Amounts Recognized on the Balance Sheets

For the year ended December 31, 2021, the pension plans had an actuarial gain primarily due to an increase in the discount rate, partially offset by less favorable demographic experience than expected, resulting from the updated census information as of January 1, 2021. For the year ended December 31, 2021, the OPEB plans had an actuarial gain primarily due to an increase in the discount rate and an update of the projected reimbursements from the Employer Group Waiver Program under Medicare Part D. For the year ended December 31, 2020, the pension plans had an actuarial loss primarily due to a decrease in the discount rate, partially offset by a decrease in the assumed rate used to convert account balances to annuities. For the year ended December 31, 2020, the OPEB plans had an actuarial loss primarily due to a decrease in the discount rate and an update to the health care trend assumption, partially offset by updated projected per capita claims costs due to rate negotiations for Medicare advantage premium rates.
The following tables provide a reconciliation of the changes in the plans’ benefit obligations, fair value of plan assets, funded status and the presentation on the balance sheets.  The benefit obligation for the defined benefit pension and OPEB plans are the projected benefit obligation and the accumulated benefit obligation, respectively.

Pension PlansOPEB
2021202020212020
Change in Benefit Obligation(in millions)
Benefit Obligation as of January 1,$668.5 $644.9 $173.7 $178.7 
Service Cost11.9 10.5 1.0 1.1 
Interest Cost16.3 20.2 4.2 5.8 
Actuarial (Gain) Loss(28.4)39.8 (21.4)4.7 
Plan Amendments— — (0.9)(1.8)
Benefit Payments(48.6)(46.9)(19.2)(21.1)
Participant Contributions— — 6.6 6.3 
Benefit Obligation as of December 31,$619.7 $668.5 $144.0 $173.7 
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,$695.7 $632.0 $292.6 $270.6 
Actual Gain on Plan Assets30.5 103.6 22.0 36.8 
Company Contributions— 7.0 — — 
Participant Contributions— — 6.6 6.3 
Benefit Payments(48.6)(46.9)(19.2)(21.1)
Fair Value of Plan Assets as of December 31,$677.6 $695.7 $302.0 $292.6 
Funded Status as of December 31,$57.9 $27.2 $158.0 $118.9 

Amounts Recognized on the Balance Sheets;
Pension PlansOPEB
December 31,
2021202020212020
(in millions)
Special Funds – Prepaid Benefit Costs
$58.7 $27.7 $158.0 $118.9 
Accumulated Provision for Pensions and Benefits – Long-term Benefit Liability
(0.8)(0.5)— — 
Funded Status$57.9 $27.2 $158.0 $118.9 
Amounts Included in Regulatory Assets, Deferred Income Taxes and AOCI

The following tables show the components of the plans included in Regulatory Assets, Deferred Income Taxes, and AOCI:


Pension PlansOPEB
December 31,
2021202020212020
Components(in millions)
Net Actuarial (Gain) Loss$82.5 $124.7 $(18.5)$11.5 
Prior Service Credit— — (23.7)(33.2)
Recorded as
Regulatory Assets$82.5 $124.7 $(19.8)$(10.3)
Deferred Income Taxes— — (4.7)(2.4)
Net of Tax AOCI— — (17.7)(9.0)

Components of the change in amounts included in Regulatory Assets, Deferred Income Taxes, and AOCI were as follows:

Pension PlansOPEB
2021202020212020
Components(in millions)
Actuarial Gain During the Year$(30.2)$(30.4)$(30.0)$(17.6)
Amortization of Actuarial Loss(12.0)(11.2)— (0.9)
Prior Service Credit— — (0.8)(1.9)
Amortization of Prior Service Credit— — 10.3 10.2 
Change for the Year Ended December 31,$(42.2)$(41.6)$(20.5)$(10.2)

Determination of Pension Expense

The determination of pension expense or income is based on a market-related valuation of assets which reduces year-to-year volatility.  This market-related valuation recognizes investment gains or losses over a five-year period from the year in which they occur.  Investment gains or losses for this purpose are the difference between the expected return calculated using the market-related value of assets and the actual return.

Pension and OPEB Assets

The fair value tables within Pension and OPEB Assets present the classification of assets for AEP within the fair value hierarchy. All Level 1, 2, 3 and Other amounts can be allocated to APCo using the percentages in the table below:

Pension PlanOPEB
December 31,
2021202020212020
12.7 %12.5 %14.8 %15.0 %
The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2021:
Asset ClassLevel 1Level 2Level 3OtherTotal
Year End
Allocation
(in millions)
Equities (a):
Domestic$388.9 $— $— $— $388.9 7.2 %
International465.7 — — — 465.7 8.7 %
Common Collective Trusts (c)
— — — 463.9 463.9 8.7 %
Subtotal – Equities854.6 — — 463.9 1,318.5 24.6 %
Fixed Income (a):
United States Government and Agency Securities
0.1 1,557.6 — — 1,557.7 29.1 %
Corporate Debt— 1,295.9 — — 1,295.9 24.2 %
Foreign Debt— 259.4 — — 259.4 4.8 %
State and Local Government— 57.1 — — 57.1 1.1 %
Other – Asset Backed— 1.3 — — 1.3 — %
Subtotal – Fixed Income0.1 3,171.3 — — 3,171.4 59.2 %
Infrastructure (c)— — — 92.1 92.1 1.7 %
Real Estate (c)— — — 232.6 232.6 4.4 %
Alternative Investments (c)— — — 448.8 448.8 8.4 %
Cash and Cash Equivalents (c)— 64.3 — 53.4 117.7 2.2 %
Other – Pending Transactions and Accrued Income (b)
— — — (28.2)(28.2)(0.5)%
Total$854.7 $3,235.6 $— $1,262.6 $5,352.9 100.0 %

(a)Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information.
(b)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.
(c)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.
The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2021:

Asset ClassLevel 1Level 2Level 3OtherTotal
Year End
Allocation
(in millions)
Equities:
Domestic$474.0 $— $— $— $474.0 23.2 %
International296.3 — — — 296.3 14.5 %
Common Collective Trusts (b)
— — — 265.0 265.0 13.0 %
Subtotal – Equities770.3 — — 265.0 1,035.3 50.7 %
Fixed Income:
Common Collective Trust – Debt (b)— — — 167.7 167.7 8.2 %
United States Government and Agency Securities
— 222.4 — — 222.4 10.9 %
Corporate Debt— 233.2 — — 233.2 11.4 %
Foreign Debt— 39.8 — — 39.8 2.0 %
State and Local Government91.9 13.6 — — 105.5 5.1 %
Subtotal – Fixed Income91.9 509.0 — 167.7 768.6 37.6 %
Trust Owned Life Insurance:
International Equities— 23.4 — — 23.4 1.1 %
United States Bonds— 171.3 — — 171.3 8.4 %
Subtotal – Trust Owned Life Insurance— 194.7 — — 194.7 9.5 %
Cash and Cash Equivalents (b)33.0 — — 6.7 39.7 1.9 %
Other – Pending Transactions and Accrued Income (a)
— — — 6.0 6.0 0.3 %
Total$895.2 $703.7 $— $445.4 $2,044.3 100.0 %
 

(a)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.
(b)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.
The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2020:
Asset ClassLevel 1Level 2Level 3OtherTotal
Year End
Allocation
(in millions)
Equities (a):
Domestic$542.3 $— $— $— $542.3 9.7 %
International676.3 — — — 676.3 12.2 %
Common Collective Trusts (c)
— — — 650.0 650.0 11.7 %
Subtotal – Equities1,218.6 — — 650.0 1,868.6 33.6 %
Fixed Income (a):
United States Government and Agency Securities
(1.4)1,134.1 — — 1,132.7 20.4 %
Corporate Debt— 1,425.0 — — 1,425.0 25.6 %
Foreign Debt— 214.0 — — 214.0 3.9 %
State and Local Government— 56.0 — — 56.0 1.0 %
Other – Asset Backed— 0.8 — — 0.8 — %
Subtotal – Fixed Income(1.4)2,829.9 — — 2,828.5 50.9 %
Infrastructure (c)— — — 91.1 91.1 1.6 %
Real Estate (c)— — — 231.6 231.6 4.2 %
Alternative Investments (c)— — — 431.8 431.8 7.8 %
Cash and Cash Equivalents (c)— 49.3 — 58.2 107.5 1.9 %
Other – Pending Transactions and Accrued Income (b)
— — — (2.5)(2.5)— %
Total$1,217.2 $2,879.2 $— $1,460.2 $5,556.6 100.0 %

(a)Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information.
(b)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.
(c)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.
The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2020:
Asset ClassLevel 1Level 2Level 3OtherTotal
Year End
Allocation
(in millions)
Equities:
Domestic
$399.9 $— $— $— $399.9 20.6 %
International
290.7 — — — 290.7 14.9 %
Common Collective Trusts (b)
— — — 264.7 264.7 13.6 %
Subtotal – Equities690.6 — — 264.7 955.3 49.1 %
Fixed Income:
Common Collective Trust – Debt (b)
— — — 186.4 186.4 9.6 %
United States Government and Agency Securities
(0.2)199.7 — — 199.5 10.2 %
Corporate Debt
— 248.7 — — 248.7 12.8 %
Foreign Debt
— 34.9 — — 34.9 1.8 %
State and Local Government
73.9 13.1 — — 87.0 4.5 %
Subtotal – Fixed Income73.7 496.4 — 186.4 756.5 38.9 %
Trust Owned Life Insurance:
International Equities
— 64.8 — — 64.8 3.3 %
United States Bonds
— 135.9 — — 135.9 7.0 %
Subtotal – Trust Owned Life Insurance— 200.7 — — 200.7 10.3 %
Cash and Cash Equivalents (b)26.3 — — 5.7 32.0 1.6 %
Other – Pending Transactions and Accrued Income (a)
— — — 2.2 2.2 0.1 %
Total$790.6 $697.1 $— $459.0 $1,946.7 100.0 %

(a)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.
(b)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.

Accumulated Benefit Obligation

The accumulated benefit obligation for the pension plans is as follows:
December 31,
Accumulated Benefit Obligation20212020
(in millions)
Qualified Pension Plan$595.0 $643.5 
Nonqualified Pension Plans0.4 0.2 
Total$595.4 $643.7 
Obligations in Excess of Fair Values

The tables below show the underfunded pension plans that had obligations in excess of plan assets.

Projected Benefit Obligation
December 31,
20212020
(in millions)
Projected Benefit Obligation$0.8 $0.5 
Fair Value of Plan Assets— — 
Underfunded Projected Benefit Obligation
$(0.8)$(0.5)


Accumulated Benefit Obligation
December 31,
20212020
(in millions)
Accumulated Benefit Obligation$0.4 $0.2 
Fair Value of Plan Assets— — 
Underfunded Accumulated Benefit Obligation
$(0.4)$(0.2)

Estimated Future Benefit Payments and Contributions

APCo expects contributions and payments for the Pension plans of $1 million during 2022. The estimated contributions to the pension trust are at least the minimum amount required by the Employee Retirement Income Security Act and additional discretionary contributions may also be made to maintain the funded status of the plan.

The table below reflects the total benefits expected to be paid from the plan or from APCo’s assets.  The payments include the participants’ contributions to the plan for their share of the cost.  Future benefit payments are dependent on the number of employees retiring, whether the retiring employees elect to receive pension benefits as annuities or as lump sum distributions, future integration of the benefit plans with changes to Medicare and other legislation, future levels of interest rates and variances in actuarial results.  The estimated payments for the pension benefits and OPEB are as follows:
Estimated Payments
Pension PlansOPEB
(in millions)
2022$43.7 $18.7 
202344.8 17.3 
202445.3 18.0 
202543.0 17.5 
202643.3 17.1 
Years 2027 to 2031, in Total202.2 80.0 
 
Components of Net Periodic Benefit Cost

The following table provides the components of net periodic benefit cost (credit) for the plans:

Pension PlansOPEB
Years Ended December 31,
2021202020212020
(in millions)
Service Cost$11.9 $10.5 $1.0 $1.1 
Interest Cost16.3 20.2 4.2 5.8 
Expected Return on Plan Assets(28.8)(33.4)(13.4)(14.5)
Amortization of Prior Service Credit— — (10.3)(10.2)
Amortization of Net Actuarial Loss12.0 11.2 — 0.9 
Net Periodic Benefit Cost (Credit)11.4 8.5 (18.5)(16.9)
Capitalized Portion(5.2)(4.5)(0.4)(0.5)
Net Periodic Benefit Cost (Credit) Recognized in Expense
$6.2 $4.0 $(18.9)$(17.4)


American Electric Power System Retirement Savings Plan

APCo participates in an AEP sponsored defined contribution retirement savings plan, the American Electric Power System Retirement Savings Plan, for substantially all employees. This qualified plan offers participants an opportunity to contribute a portion of their pay, includes features under Section 401(k) of the Internal Revenue Code and provides for company matching contributions. The matching contributions to the plan are 100% of the first 1% of eligible employee contributions and 70% of the next 5% of contributions. The cost for matching contributions to the retirement savings plan for the years ended December 31, 2021 and 2020 were $8 million and $8 million, respectively.
8.  BUSINESS SEGMENTS

APCo has one reportable segment, an electricity generation, transmission and distribution business. APCo’s other activities are insignificant.
9.  DERIVATIVES AND HEDGING

OBJECTIVES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS

AEPSC is agent for and transacts on behalf of APCo.

APCo is exposed to certain market risks as major power producer and participant in the electricity, capacity, natural gas, coal and emission allowance markets. These risks include commodity price risks which may be subject to capacity risk, interest rate risk and credit risk. These risks represent the risk of loss that may impact APCo due to changes in the underlying market prices or rates. Management utilizes derivative instruments to manage these risks.

STRATEGIES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS TO ACHIEVE OBJECTIVES

Risk Management Strategies

The strategy surrounding the use of derivative instruments primarily focuses on managing risk exposures, future cash flows and creating value utilizing both economic and formal hedging strategies.  The risk management strategies also include the use of derivative instruments for trading purposes which focus on seizing market opportunities to create value driven by expected changes in the market prices of the commodities.  To accomplish these objectives, APCo primarily employs risk management contracts including physical and financial forward purchase-and-sale contracts and, to a lesser extent, OTC swaps and options.  Not all risk management contracts meet the definition of a derivative under the accounting guidance for “Derivatives and Hedging.”  Derivative risk management contracts elected normal under the normal purchases and normal sales scope exception are not subject to the requirements of this accounting guidance.

APCo utilizes power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other commodity contracts to manage the risk associated with the energy business. APCo utilizes interest rate derivative contracts in order to manage the interest rate exposure associated with the commodity portfolio. For disclosure purposes, such risks are grouped as “Commodity,” as these risks are related to energy risk management activities. APCo also utilizes derivative contracts to manage interest rate risk associated with debt financing. For disclosure purposes, these risks are grouped as “Interest Rate.” The amount of risk taken is determined by the Commercial Operations and Finance groups in accordance with established risk management policies as approved by the Finance Committee of the Board of Directors.
The following table represents the gross notional volume of outstanding derivative contracts:

Notional Volume of Derivative Instruments
Volume
December 31,
Primary Risk Exposure20212020Unit of Measure
(in millions)
Commodity:
Power33.1 46.9 MWhs
Heating Oil and Gasoline
1.1 1.1 Gallons
Interest Rate on Long-term Debt$— $200.0 USD

Cash Flow Hedging Strategies

APCo utilizes cash flow hedges on certain derivative transactions for the purchase-and-sale of power (“Commodity”) in order to manage the variable price risk related to forecasted purchases and sales.  Management monitors the potential impacts of commodity price changes and, where appropriate, enters into derivative transactions to protect profit margins for a portion of future electricity sales and purchases.  APCo does not hedge all commodity price risk.

APCo utilizes a variety of interest rate derivative transactions in order to manage interest rate risk exposure.  APCo also utilizes interest rate derivative contracts to manage interest rate exposure related to future borrowings of fixed-rate debt.  APCo does not hedge all interest rate exposure.
ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND THE IMPACT ON THE FINANCIAL STATEMENTS

The accounting guidance for “Derivatives and Hedging” requires recognition of all qualifying derivative instruments as either assets or liabilities on the balance sheets at fair value.  The fair values of derivative instruments accounted for using MTM accounting or hedge accounting are based on exchange prices and broker quotes.  If a quoted market price is not available, the estimate of fair value is based on the best information available including valuation models that estimate future energy prices based on existing market and broker quotes and other assumptions.  In order to determine the relevant fair values of the derivative instruments, APCo applies valuation adjustments for discounting, liquidity and credit quality.

Credit risk is the risk that a counterparty will fail to perform on the contract or fail to pay amounts due.  Liquidity risk represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon prevailing market supply and demand conditions.  Since energy markets are imperfect and volatile, there are inherent risks related to the underlying assumptions in models used to fair value risk management contracts.  Unforeseen events may cause reasonable price curves to differ from actual price curves throughout a contract’s term and at the time a contract settles.  Consequently, there could be significant adverse or favorable effects on future net income and cash flows if market prices are not consistent with management’s estimates of current market consensus for forward prices in the current period.  This is particularly true for longer term contracts.  Cash flows may vary based on market conditions, margin requirements and the timing of settlement of risk management contracts.

According to the accounting guidance for “Derivatives and Hedging,” APCo reflects the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral.  For certain risk management contracts, APCo is required to post or receive cash collateral based on third-party contractual agreements and risk profiles.  The netted cash collateral from third-parties against short-term and long-term risk management assets and netted cash collateral paid to third-parties against short-term and long-term risk management liabilities were immaterial as of December 31, 2021 and 2020.
The following tables represent the gross fair value of APCo’s derivative activity on the balance sheets:


December 31, 2021
Risk ManagementGross Amounts OffsetNet Amounts of Assets/Liabilities
Contracts -in the Statement ofPresented in the Statement
Balance Sheet LocationCommodity (a)Financial Position (b)of Financial Position (c)
(in millions)
Derivative Instrument Assets$47.7 $(5.7)$42.0 
Long-Term Portion of Derivative Instrument Assets0.2 (0.2)— 
Derivative Instrument Liabilities7.4 (6.6)0.8 
Long-Term Portion of Derivative Instrument Liabilities0.2 (0.2)— 

December 31, 2020
RiskGross Amounts of RiskGross AmountsNet Amounts of Assets/
ManagementHedgingManagementOffset in theLiabilities Presented in
Contracts -ContractsAssets/LiabilitiesStatement ofthe Statement of
Balance Sheet LocationCommodity (a)Interest Rate (a)RecognizedFinancial Position (b)Financial Position (c)
(in millions)
Derivative Instrument Assets$39.5 $2.4 $41.9 $(19.4)$22.5 
Long-Term Portion of Derivative Instrument Assets
0.7 — 0.7 (0.6)0.1 
Derivative Instrument Liabilities20.3 3.4 23.7 (19.0)4.7 
Long-Term Portion of Derivative Instrument Liabilities
0.6 — 0.6 (0.5)0.1 

(a)Derivative instruments within this category are disclosed as gross.  These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.”
(b)Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.”
(c)All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position.
The table below presents the activity of derivative risk management contracts:

Amount of Gain (Loss) Recognized on Risk Management Contracts
Years Ended December 31,
Location of Gain (Loss)
20212020
(in millions)
Operating Revenues$(0.5)$0.4 
Operation Expenses2.1 1.0 
Maintenance Expenses0.5 (0.4)
Other Regulatory Assets (a)(2.7)— 
Other Regulatory Liabilities (a)55.9 20.3 
Total Gain (Loss) on Risk Management Contracts
$55.3 $21.3 

(a)Represents realized and unrealized gains and losses subject to regulatory accounting treatment.

Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided in the accounting guidance for “Derivatives and Hedging.”  Derivative contracts that have been designated as normal purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are recognized on the statements of income on an accrual basis.

The accounting for the changes in the fair value of a derivative instrument depends on whether it qualifies for and has been designated as part of a hedging relationship and further, on the type of hedging relationship.  Depending on the exposure, management designates a hedging instrument as a fair value hedge or a cash flow hedge.

For contracts that have not been designated as part of a hedging relationship, the accounting for changes in fair value depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains and losses on derivative instruments held for trading purposes are included in revenues on a net basis on the statements of income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in revenues or expenses on the statements of income depending on the relevant facts and circumstances. Certain derivatives that economically hedge future commodity risk are recorded in the same line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.”
Accounting for Cash Flow Hedging Strategies

For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), APCo initially reports the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income on the balance sheets until the period the hedged item affects Net Income.  

Realized gains and losses on derivative contracts for the purchase and sale of power designated as cash flow hedges are included in Operating Revenues or Operation Expenses on the statements of income or in Other Regulatory Assets or Other Regulatory Liabilities on the balance sheets, depending on the specific nature of the risk being hedged.  During the years ended 2021 and 2020, APCo did not apply cash flow hedging to outstanding power derivatives.

APCo reclassifies gains and losses on interest rate derivative hedges related to debt financings from Accumulated Other Comprehensive Income on the balance sheets into Interest on Long-term Debt on the statements of income in those periods in which hedged interest payments occur.  During the years ended 2021 and 2020, APCo applied cash flow hedging to outstanding interest rate derivatives.

For details on effective cash flow hedges included in Accumulated Other Comprehensive Income on the balance sheets and the reasons for changes in cash flow hedges, see Note 3 - Comprehensive Income.

Cash flow hedges included in Accumulated Other Comprehensive Income on the balance sheets were:

Impact of Cash Flow Hedges on the Balance Sheets
December 31, 2021December 31, 2020
Interest Rate
Expected to beExpected to be
Reclassed toReclassed to
Net Income DuringNet Income During
AOCI Gain (Loss)the NextAOCI Gain (Loss)the Next
Net of TaxTwelve MonthsNet of TaxTwelve Months
(in millions)
$7.5 $0.8 $(0.8)$0.4 

The actual amounts reclassified from Accumulated Other Comprehensive Income to Net Income can differ from the estimate above due to market price changes.

Credit Risk

Management mitigates credit risk in wholesale marketing and trading activities by assessing the creditworthiness of potential counterparties before entering into transactions with them and continuing to evaluate their creditworthiness on an ongoing basis. Management uses credit agency ratings and current market-based qualitative and quantitative data as well as financial statements to assess the financial health of counterparties on an ongoing basis.

Master agreements are typically used to facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Collateral requirements in the form of cash, letters of credit and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. Some master agreements include margining, which requires a counterparty to post cash or letters of credit in the event exposure exceeds the established threshold. The threshold represents an unsecured credit limit which may be supported by a parental/affiliate guaranty, as determined in accordance with AEP’s credit policy. In addition, master agreements allow for termination and liquidation of all positions in the event of a default including a failure or inability to post collateral when required.
Collateral Triggering Events

Credit Downgrade Triggers

A limited number of derivative contracts include collateral triggering events, which include a requirement to maintain certain credit ratings. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these collateral triggering events in contracts. APCo has not experienced a downgrade below a specified credit rating threshold that would require the posting of additional collateral. APCo had no derivative contracts with collateral triggering events in a net liability position as of December 31, 2021 and 2020.

Cross-Default Triggers

In addition, a majority of APCo’s non-exchange-traded commodity contracts contain cross-default provisions that, if triggered, would permit the counterparty to declare a default and require settlement of the outstanding payable. These cross-default provisions could be triggered if there was a non-performance event by Parent or the obligor under outstanding debt or a third-party obligation that is $50 million or greater.  On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these cross-default provisions in the contracts. Amounts for APCo were immaterial for years ended December 31, 2021 and 2020.
10.  FAIR VALUE MEASUREMENTS

Fair Value Measurements of Long-term Debt

The fair values of Long-term Debt are based on quoted market prices, without credit enhancements, for the same or similar issues and the current interest rates offered for instruments with similar maturities classified as Level 2 measurement inputs.  These instruments are not marked-to-market.  The estimates presented are not necessarily indicative of the amounts that could be realized in a current market exchange.

The book values and fair values of Long-term Debt are summarized in the following table:
December 31,
20212020
Book ValueFair ValueBook ValueFair Value
(in millions)
$4,967.7 $6,037.1 $4,861.9 $6,391.8 


Fair Value Measurements of Financial Assets and Liabilities

For a discussion of fair value accounting and the classification of assets and liabilities within the fair value hierarchy, see the “Fair Value Measurements of Assets and Liabilities” section of Note 1.

The following tables set forth, by level within the fair value hierarchy, APCo’s financial assets and liabilities that were accounted for at fair value on a recurring basis.  As required by the accounting guidance for “Fair Value Measurements and Disclosures,” financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.  Management’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.  There have not been any significant changes in management’s valuation techniques.


December 31, 2021
Level 1Level 2Level 3OtherTotal
Assets:(in millions)
Special Deposits$17.6 $— $— $— $17.6 
Derivative Instrument Assets
Risk Management Commodity Contracts (a) (b)— 5.8 42.0 (5.8)42.0 
Total Assets$17.6 $5.8 $42.0 $(5.8)$59.6 
Liabilities:
Derivative Instrument Liabilities
Risk Management Commodity Contracts (a) (b)$— $7.2 $0.3 $(6.7)$0.8 
December 31, 2020
Level 1Level 2Level 3OtherTotal
Assets:(in millions)
Special Deposits$16.9 $— $— $— $16.9 
Derivative Instrument Assets
Risk Management Commodity Contracts (a) (b)— 19.4 19.9 (19.2)20.1 
Cash Flow Hedges:
Interest Rate Hedges— 2.4 — — 2.4 
Total Derivative Instrument Assets— 21.8 19.9 (19.2)22.5 
Total Assets$16.9 $21.8 $19.9 $(19.2)$39.4 
Liabilities:
Derivative Instrument Liabilities
Risk Management Commodity Contracts (a) (b)$— $19.5 $0.6 $(18.8)$1.3 
Cash Flow Hedges:
Interest Rate Hedges— 3.4 — — 3.4 
Total Derivative Instrument Liabilities$— $22.9 $0.6 $(18.8)$4.7 

(a)Amounts in “Other” column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.
(b)Substantially comprised of power contracts.
The following tables set forth a reconciliation of changes in the fair value of net trading derivatives classified as Level 3 in the fair value hierarchy:

Derivative Instrument
Year Ended December 31, 2021Assets (Liabilities)
 (in millions)
Balance as of December 31, 2020$19.3 
Realized Gain Included in Net Income (or Changes in Net Assets) (a) (b)8.3 
Settlements(28.0)
Transfers out of Level 3 (c)— 
Changes in Fair Value Allocated to Regulated Jurisdictions (d)42.1 
Balance as of December 31, 2021$41.7 
Derivative Instrument
Year Ended December 31, 2020Assets (Liabilities)
 (in millions)
Balance as of December 31, 2019$37.7 
Realized Gain Included in Net Income (or Changes in Net Assets) (a) (b)13.2 
Settlements(51.6)
Transfers out of Level 3 (c)0.7 
Changes in Fair Value Allocated to Regulated Jurisdictions (d)19.3 
Balance as of December 31, 2020$19.3 

(a)Included in revenues on the statements of income.
(b)Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract.
(c)Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred.
(d)Relates to the net gains (losses) of those contracts that are not reflected on the statements of income.  These changes in fair value are recorded as regulatory liabilities for net gains and as regulatory assets for net losses or accounts payable.
The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions:

December 31, 2021
SignificantInput/Range
Fair ValueValuationUnobservableWeighted
AssetsLiabilitiesTechniqueInput (a)LowHighAverage (b)
(in millions)
Energy Contracts
$— $0.3 
Discounted Cash Flow
Forward Market Price
$32.20 $56.54 $44.77 
FTRs42.0 — 
Discounted Cash Flow
Forward Market Price
(0.30)26.38 2.63 
Total$42.0 $0.3 

December 31, 2020
SignificantInput/Range
Fair ValueValuationUnobservableWeighted
AssetsLiabilitiesTechniqueInput (a)LowHighAverage (b)
(in millions)
Energy Contracts
$1.0 $0.6 
Discounted Cash Flow
Forward Market Price
$10.84 $41.09 $25.08 
FTRs18.9 — 
Discounted Cash Flow
Forward Market Price
0.04 5.61 1.13 
Total$19.9 $0.6 


(a)Represents market prices in dollars per MWh.
(b)The weighted-average is the product of the forward market price of the underlying commodity and volume weighted by term.

The following table provides the measurement uncertainty of fair value measurements to increases (decreases) in significant unobservable inputs related to Energy Contracts, Natural Gas Contracts and FTRs as of December 31, 2021 and 2020:

Uncertainty of Fair Value Measurements
Significant Unobservable InputPositionChange in Input
Impact on Fair Value
Measurement
Forward Market Price
Buy
Increase (Decrease)Higher (Lower)
Forward Market PriceSellIncrease (Decrease)Lower (Higher)
11. INCOME TAXES

Income Tax Expense (Credit)

The details of APCo’s income taxes as reported are as follows:
Years Ended December 31,
20212020
(in millions)
Charged (Credited) to Operating Expenses, Net:
Current$12.0 $36.2 
Deferred17.2 (29.4)
Total29.2 6.8 
Charged (Credited) to Non-Operating Income, Net:
Current(4.9)(5.2)
Deferred(1.7)2.8 
Total(6.6)(2.4)
Total Income Tax Expense$22.6 $4.4 
The following is a reconciliation of the difference between the amount of federal income taxes computed by multiplying book income before income taxes by the federal statutory tax rate and the amount of income taxes reported:
20212020
Net Income$348.9 $369.7 
Income Tax Expense22.6 4.4 
Pretax Income$371.5 $374.1 
Income Taxes on Pretax Income at Statutory Rate (21%)$78.0 $78.6 
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through11.7 12.7 
State and Local Income Taxes, Net1.0 7.9 
Removal Costs(7.3)(5.7)
AFUDC(4.6)(4.5)
Parent Company Loss Benefit— (6.2)
Tax Reform Excess ADIT Reversal(60.5)(72.3)
Return to Provision Adjustment(0.5)(7.1)
Tax Adjustments (a)4.9 — 
Other(0.1)1.0 
Income Tax Expense$22.6 $4.4 
Effective Income Tax Rate6.1 %1.2 %
(a) Represents the correction of an out of period adjustment related to Deferred Income Taxes and Income Tax Expense. Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements.
Net Deferred Tax Liability

The following table shows elements of APCo’s net deferred tax assets (liabilities) and significant temporary differences:
December 31,
20212020
(in millions)
Deferred Tax Assets$488.8 $494.8 
Deferred Tax Liabilities(2,298.7)(2,249.5)
Net Deferred Tax Liabilities$(1,809.9)$(1,754.7)
Property Related Temporary Differences$(1,476.5)$(1,412.0)
Amounts Due to Customers for Future Income Taxes182.1 198.3 
Deferred State Income Taxes(289.2)(336.5)
Regulatory Assets(177.0)(114.8)
Securitized Assets(39.3)(44.7)
Operating Lease Liability14.2 16.7 
All Other, Net(24.2)(61.7)
Net Deferred Tax Liabilities$(1,809.9)$(1,754.7)

AEP System Tax Allocation Agreement

APCo and other AEP subsidiaries join in the filing of a consolidated federal income tax return.  The allocation of the AEP System’s current consolidated federal income tax to the AEP System companies allocates the benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries with taxable income reducing their current tax expense proportionately.  The consolidated NOL of the AEP System is allocated to each company in the consolidated group with taxable losses. With the exception of the allocation of the consolidated AEP System NOL, the loss of the Parent and tax credits, the method of allocation reflects a separate return result for each company in the consolidated group.

Net Income Tax Operating Loss Carryforward

As of December 31, 2021, APCO had West Virginia net income tax operating loss carryforward of $62.9 million. As a result, APCO recognized deferred state income tax benefits. Management anticipates future taxable income will be sufficient to realize the state net income tax operating loss tax benefits before the state carryforward expires.

Federal and State Income Tax Audit Status

The statute of limitations for the IRS to examine APCo and other AEP subsidiaries originally filed federal return has expired for tax years 2016 and earlier. In the third quarter of 2019, APCo and other AEP subsidiaries elected to amend the 2014 through 2017 federal returns. In the first quarter of 2020, the IRS notified APCo and other AEP subsidiaries that it was beginning an examination of these amended returns, including the NOL carryback to 2015 that originated in the 2017 return. As of December 31, 2021, the IRS has not issued any proposed adjustments and the IRS is limited in their proposed adjustments to the amount APCo and other AEP subsidiaries claimed on the amended returns. APCo has agreed to extend the statute of limitations on the 2017 tax return to December 31, 2022 to allow time for the audit to be completed and the Congressional Joint Committee on Taxation to approve the associated refund claim.
APCo and AEP subsidiaries file income tax returns in various state and local jurisdictions. These taxing authorities routinely examine the tax returns, and APCo and other AEP subsidiaries are currently under examination in several state and local jurisdictions. The Registrants are no longer subject to state or local examinations by tax authorities for years before 2012. In addition, management is monitoring and continues to evaluate the potential impact of federal legislation and corresponding state conformity.

State Tax Legislation

In April 2021, West Virginia enacted House Bill (HB) 2026. HB 2026 changes the state income tax apportionment formula from a ratio that includes property, payroll and sales to a single sales factor apportionment regime effective for tax years beginning on or after January 1, 2022. HB 2026 also eliminates the “throw out” rule related to sales of tangible personal property for sales factor apportionment calculation purposes and introduces a market-based sourcing for sales of services and intangible property.
12.  LEASES

APCo leases property, plant and equipment including, but not limited to, fleet, information technology and real estate leases. These leases require payments of non-lease components, including related property taxes, operating and maintenance costs. APCo does not separate non-lease components from associated lease components. Many of these leases have purchase or renewal options. Leases not renewed are often replaced by other leases. Options to renew or purchase a lease are included in the measurement of lease assets and liabilities if it is reasonably certain APCo will exercise the option.

Lease obligations are measured using the discount rate implicit in the lease when that rate is readily determinable. AEP has visibility into the rate implicit in the lease when assets are leased from selected financial institutions under master leasing agreements. When the implicit rate is not readily determinable, APCo measures its lease obligation using its estimated secured incremental borrowing rate. Incremental borrowing rates are comprised of an underlying risk-free rate and a secured credit spread relative to the lessee on a matched maturity basis.

Operating and Finance lease rental costs are generally charged to Operation Expense and Maintenance Expense in accordance with rate-making treatment for regulated operations. Lease costs associated with capital projects are included in Utility Plant on the balance sheets. For regulated operations with finance leases, a finance lease asset and offsetting liability are recorded at the present value of the remaining lease payments for each reporting period.  The components of rental costs were as follows:
Years Ended December 31,
20212020
(in millions)
Operating Lease Cost$19.3 $19.1 
Finance Lease Cost:
Amortization of Right-of-Use Assets
7.7 7.4 
Interest on Lease Liabilities
2.4 2.7 
Total Lease Rental Costs (a)$29.4 $29.2 

(a)Excludes variable and short-term lease costs, which were immaterial.
Supplemental information related to leases are shown in the tables below:
December 31,
20212020
Weighted-Average Remaining Lease Term (years):
Operating Leases5.686.27
Finance Leases4.975.75
Weighted-Average Discount Rate:
Operating Leases3.42 %3.48 %
Finance Leases7.16 %7.33 %


Year Ended December 31,
20212020
(in millions)
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows from Operating Leases
$19.3 $19.2 
Operating Cash Flows from Finance Leases
10.1 10.1 
Non-cash Acquisitions Under Operating Leases$4.2 $16.2 
The following tables show property, plant and equipment under finance leases, operating leases and related obligations recorded on APCo’s balance sheets:
December 31,
20212020
(in millions)
Property, Plant and Equipment Under Finance Leases:
Utility Plant (a)$35.7 $41.7 
Net Property, Plant and Equipment Under Finance Leases$35.7 $41.7 
Obligations Under Finance Leases:
Noncurrent$28.1 $34.4 
Current7.6 7.3 
Total Obligations Under Finance Leases$35.7 $41.7 
(a)    Includes $28 million and $22 million of accumulated provision for depreciation and amortization for
the years ended December 31, 2021 and 2020, respectively.

December 31,
20212020
(in millions)
Property, Plant and Equipment Under Operating Leases:
Utility Plant (a)$66.9 $78.8 
Net Property, Plant and Equipment Under Operating Leases$66.9 $78.8 
Obligations Under Operating Leases:
Noncurrent$52.4 $64.4 
Current15.1 14.9 
Total Obligations Under Operating Leases$67.5 $79.3 
(a)    Includes $38 million and $25 million of accumulated provision for depreciation and amortization for
the years ended December 31, 2021 and 2020, respectively.
Future minimum lease payments consisted of the following as of December 31, 2021:

Finance LeasesOperating Leases
(in millions)
2022$9.8 $17.5 
20239.1 14.8 
20248.3 11.9 
20257.2 9.1 
20262.7 7.2 
After 20264.1 14.1 
Total Future Minimum Lease Payments41.2 74.6 
Less: Imputed Interest5.5 7.1 
Estimated Present Value of Future Minimum Lease Payments$35.7 $67.5 

Master Lease Agreements

APCo leases certain equipment under master lease agreements.  Under the lease agreements, the lessor is guaranteed a residual value up to a stated percentage of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed residual value at the end of the lease term, APCo is committed to pay the difference between the actual fair value and the residual value guarantee.  Historically, at the end of the lease term the fair value has been in excess of the amount guaranteed.  As of December 31, 2021, the maximum potential loss by APCo for these lease agreements assuming the fair value of the equipment is zero at the end of the lease term was $6 million.

Lessor Activity

APCo’s lessor activity was immaterial as of and for the twelve months ended December 31, 2021 and December 31, 2020, respectively.
13.  FINANCING ACTIVITIES

Long-term Debt

The following table details long-term debt outstanding:
Weighted-AverageInterest Rate Ranges as ofOutstanding as of
Interest Rate as ofDecember 31,December 31,
MaturityDecember 31, 20212021202020212020
Senior Unsecured Notes2021-20504.70%2.70%-7.00%3.30%-7.00%$4,125.0 $3,975.0 
Pollution Control Bonds (a)2021-2036 (b)1.67%0.19%-2.75%0.19%-4.63%531.0 548.5 
Securitization Bonds2023-2028 (c)3.46%2.01%-3.77%2.01%-3.77%200.1 225.5 
Other Long-term Debt2022-20261.42%1.24%-13.72%1.32%-13.72%126.9 127.0 
Unamortized Discount, Net(15.3)(14.1)
Total Long-term Debt Outstanding
$4,967.7 $4,861.9 

(a)For certain series of Pollution Control Bonds, interest rates are subject to periodic adjustment.  Certain series may be purchased on demand at periodic interest adjustment dates.  Letters of credit from banks and insurance policies support certain series. Consequently, these bonds have been classified for maturity purposes as Long-term Debt Due Within One Year - Nonaffiliated on the balance sheets.
(b)Certain Pollution Control Bonds are subject to redemption earlier than the maturity date.
(c)Dates represent the scheduled final payment dates for the securitization bonds. The legal maturity date is one to two years later. These bonds have been classified for maturity and repayment purposes based on the scheduled final payment date.


As of December 31, 2021, long-term debt was payable as follows:
(in millions)
2022$480.7 
202326.6 
2024113.5 
2025443.9 
202630.9 
After 20263,887.4 
Principal Amount4,983.0 
Unamortized Discount, Net
(15.3)
Total Long-term Debt
$4,967.7 


Long-term Debt Subsequent Events

In February 2022, APCo retired $13 million of Securitization Bonds.

Dividend Restrictions

APCo pays dividends to Parent provided funds are legally available. Various financing arrangements and regulatory requirements may impose certain restrictions on the ability of APCo to transfer funds to Parent in the form of dividends.

All of the dividends declared by APCo are subject to a Federal Power Act restriction that prohibits the payment of dividends out of capital accounts without regulatory approval; payment of dividends is allowed out of retained earnings only. However, the Federal Power Act creates a reserve on retained earnings attributable to hydroelectric generation plants. Because of their ownership of such plants, this reserve applies to APCo.

APCo has credit agreements that contain covenants that limit their debt to capitalization ratio to 67.5%. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements.
The most restrictive dividend limitation for APCo is through the Federal Power Act restriction. As of December 31, 2021, the maximum amount of restricted net assets of APCo that may not be distributed to the Parent in the form of a loan, advance or dividend was $2.4 billion.

The Federal Power Act restriction limits the ability of APCo to pay dividends out of retained earnings because of their ownership in hydroelectric generation. As of December 31, 2021, the amount of any such restrictions was $313 million.

Corporate Borrowing Program – AEP System

The AEP System uses a corporate borrowing program to meet the short-term borrowing needs of AEP’s subsidiaries. The corporate borrowing program includes a Utility Money Pool, which funds AEP’s utility subsidiaries. The AEP System Utility Money Pool operates in accordance with the terms and conditions of its agreement filed with the FERC. The amounts of outstanding borrowings from the Utility Money Pool as of December 31, 2021 and 2020 are included in Notes Receivable from Associated Companies and Notes Payable to Associated Companies, respectively, on the balance sheets. APCo’s money pool activity and corresponding authorized borrowing limits are described in the following table:
MaximumAverage
BorrowingsMaximumBorrowingsAverageBorrowings fromAuthorized
from theLoans to thefrom theLoans to thethe Utility MoneyShort-term
Years endedUtilityUtilityUtilityUtilityPool as ofBorrowing
December 31,Money PoolMoney PoolMoney PoolMoney PoolDecember 31,Limit
(in millions)
2021$199.3 $595.9 $87.5 $118.3 $199.3 $500.0 
2020434.3 167.3 292.7 94.3 18.6 500.0 

The maximum, minimum and average interest rates for funds either borrowed from or loaned to the Utility Money Pool are summarized in the following table:
MaximumMinimumMaximumMinimumAverageAverage
Interest RatesInterest RatesInterest RatesInterest RatesInterest RateInterest Rate
for Fundsfor Fundsfor Fundsfor Fundsfor Fundsfor Funds
Borrowed fromBorrowed fromLoaned to theLoaned to theBorrowed fromLoaned to the
Years endedthe Utilitythe UtilityUtility MoneyUtility Moneythe UtilityUtility Money
December 31,Money PoolMoney PoolPoolPoolMoney PoolPool
(in millions)
20210.48 %0.06 %0.40 %0.02 %0.41 %0.25 %
20202.70 %0.27 %2.14 %0.27 %2.13 %0.72 %

Interest expense and interest income related to the Utility Money Pool financing relationship are included in Interest on Debt to Associated Companies and Interest and Dividend Income, respectively, on the statements of income. The interest expense and interest income related to the corporate borrowing programs were immaterial for the years ended December 31, 2021 and 2020.

Securitized Accounts Receivables – AEP Credit

Under this sale of receivables arrangement, APCo sells, without recourse, certain of its customer accounts receivable and accrued utility revenue balances to AEP Credit and is charged a fee based on AEP Credit’s financing costs, administrative costs and uncollectible accounts experience for APCo’s receivables. APCo does not have regulatory authority to sell its West Virginia accounts receivable. The costs of customer accounts receivable sold are reported in Other Deductions on APCo’s statements of income. APCo manages and services its customer
accounts receivable, which are sold to AEP Credit. AEP Credit securitizes the eligible receivables for APCo and retains the remainder.

AEP Credit has a receivables securitization agreement that provides a commitment of $750 million from bank conduits to purchase receivables and and was amended in September 2021 to include a $125 million and a $625 million facility, which expire in September 2023 and 2024, respectively.

The amount of accounts receivable and accrued utility revenues under the sale of receivables agreement as of December 31, 2021 and 2020 were $153 million and $136 million, respectively.

The fees paid to AEP Credit for customer accounts receivable sold were $5 million and $5 million for the years ended December 31, 2021 and 2020, respectively. In 2020, an increase in allowance for doubtful accounts was recognized in response to the anticipated impact of COVID-19 on the collectability of accounts receivable, which caused an increase in fees paid by APCo. In 2021, due to higher than expected collections of accounts receivables, allowance for doubtful accounts was adjusted resulting in the issuance of credits to offset the higher fees previously paid and to lower subsequent fees paid.

The proceeds on the sale of receivables to AEP Credit were $1.3 billion and $1.3 billion for the years ended December 31, 2021 and 2020, respectively.
14.  RELATED PARTY TRANSACTIONS

For other related party transactions, also see “AEP System Tax Allocation Agreement” section of Note 11 in addition to “Corporate Borrowing Program – AEP System” and “Securitized Accounts Receivables – AEP Credit” sections of Note 13.

Power Coordination Agreement

Effective January 1, 2014, the FERC approved the PCA. Under the PCA, APCo, I&M, KPCo and WPCo are individually responsible for planning their respective capacity obligations. The PCA allows, but does not obligate, APCo, I&M, KPCo and WPCo to participate collectively under a common fixed resource requirement capacity plan in PJM and to participate in specified collective off-system sales and purchase activities.

AEPSC conducts power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other risk management activities on behalf of APCo, I&M, KPCo, PSO, SWEPCo and WPCo. Certain power and natural gas risk management activities for APCo, I&M, KPCo and WPCo are allocated based on the four member companies’ respective equity positions, while power and natural gas risk management activities for PSO and SWEPCo are allocated based on the Operating Agreement.

System Integration Agreement

Under the SIA, AEPSC allocates physical and financial revenues and expenses from transactions with neighboring utilities, power marketers and other power and natural gas risk management activities based upon the location of such activity. Margins resulting from trading and marketing activities originating in PJM generally accrue to the benefit of APCo, I&M, KPCo and WPCo.  Margins resulting from other transactions are allocated among APCo, I&M, KPCo, PSO, SWEPCo and WPCo based upon the equity positions of these companies.

Affiliated Revenues and Purchases

The following table shows the revenues derived from direct sales to affiliates, auction sales to affiliates, net transmission agreement sales and other revenues for the years ended December 31, 2021 and 2020:

Years Ended December 31,
Related Party Revenues20212020
(in millions)
Direct Sales to East Affiliates$128.6 $112.5 
Auction Sales to OPCo (a)— 5.3 
Transmission Revenues60.3 49.1 
Other Revenues9.0 7.8 
(a)Refer to the Ohio Auctions section below for further information regarding these amounts.

PJM and SPP Transmission Service Charges

The AEP East Companies are parties to the TA, which defines how transmission costs through the PJM OATT are allocated among the AEP East Companies on a 12-month average coincident peak basis. Additional costs for transmission services provided by AEPTCo and other transmission affiliates are billed to AEP East Companies through the PJM OATT. APCo’s net charges for the years ended December 31, 2021 and 2020 related to the TA were $302 million and $243 million, respectively. The charges were recorded in Operation Expenses on the statements of income.
Joint License Agreement

AEPTCo entered into a 50-year joint license agreement with APCo allowing either party to occupy the granting party’s facilities or real property. In addition, AEPTCo entered into a 5-year joint license agreement with APCo and WPCo. After the expiration of the agreement, the term shall automatically renew for successive one-year terms unless either party provides notice. The joint license billing provides compensation to the granting party for the cost of carrying assets, including depreciation expense, property taxes, interest expense, return on equity and income taxes. For the years ended December 31, 2021 and 2020, AEPTCo billed APCo $2 million and $900 thousand, respectively.

OVEC

AEP and several nonaffiliated utility companies jointly own OVEC. As of December 31, 2021, the ownership and investment in OVEC were as follows:
December 31, 2021
CompanyOwnershipInvestment
(in millions)
Parent39.17 %$4.0 
OPCo4.30 %0.4 
Total43.47 %$4.4 

OVEC’s owners, along with APCo and I&M, are members to an intercompany power agreement. Participants of this agreement are entitled to receive and obligated to pay for all OVEC generating capacity, approximately 2,400 MWs, in proportion to their respective power participation ratios. The aggregate power participation ratio of certain AEP utility subsidiaries, including APCo, I&M and OPCo, is 43.47%. The proceeds from the sale of power by OVEC are designed to be sufficient for OVEC to meet its operating expenses and fixed costs, including outstanding indebtedness, and provide a return on capital. The intercompany power agreement ends in June 2040.

AEP and other nonaffiliated owners authorized environmental investments related to their ownership interests. OVEC financed capital expenditures in connection with the engineering and construction of FGD projects and the associated waste disposal landfills at its two generation plants. These environmental projects were funded through debt issuances. As of December 31, 2021 and 2020, OVEC’s outstanding indebtedness was approximately $1.1 billion and $1.3 billion, respectively. Although they are not an obligor or guarantor, AEP utility subsidiaries are responsible for their respective ratio of OVEC’s outstanding debt through the intercompany power agreement. Principal and interest payments related to OVEC’s outstanding indebtedness are disclosed in accordance with the accounting guidance for “Commitments.” See the “Commitments” section of Note 6 for additional information.

Purchased Power from OVEC

APCo paid $104 million and $94 million for power purchased from OVEC for the years ended December 31, 2021 and 2020, respectively. The amounts shown above are recoverable from customers and are included in Operating Revenues and Operation Expenses on the statement of income.

Ohio Auctions

In connection with OPCo’s June 2012 - May 2015 ESP, the Public Utilities Commission of Ohio ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning in June 2015. APCo, KPCo,
I&M and WPCo participate in the auction process and have been awarded tranches of OPCo’s SSO load. Refer to the Affiliated Revenues and Purchases section above for amounts related to these transactions.

I&M Barging, Urea Transloading and Other Services

I&M provides barging, urea transloading and other transportation services to affiliates. Urea is a chemical used to control NOx emissions at certain generation plants in the AEP System. APCo recorded the costs paid to I&M of $40 million and $44 million for the years ended December 31, 2021 and 2020, respectively, as Operation Expenses.

Central Machine Shop

APCo operates a facility which repairs and rebuilds specialized components for the generation plants across the AEP System. APCo defers the cost of performing these services on the balance sheet and then transfers the cost to the affiliate for reimbursement. APCo billed its affiliates $8 million and $8 million for the years ended December 31, 2021 and 2020, respectively.

Sales and Purchases of Property

APCo had affiliated sales and purchases of electric property amounting to $100 thousand or more, sales and purchases of meters and transformers, and sales and purchases of transmission property. There were no gains or losses recorded on the transactions. The following table shows the sales and purchases, recorded at net book value:
Years Ended December 31,
20212020
(in millions)
Sales$6.2 $5.7 
Purchases1.0 1.3 

The amounts above are recorded in Utility Plant on the balance sheets.

Intercompany Billings

APCo performs certain utility services for each other when necessary or practical.  The costs of these services are billed on a direct-charge basis, whenever possible, or on reasonable basis of proration for services that benefit multiple companies.  The billings for services are made at cost and include no compensation for the use of equity capital.

AEPSC

AEPSC provides certain managerial and professional services to APCo. The costs of the services are based on a direct charge or on a prorated basis and billed to APCo at AEPSC’s cost. AEPSC and its billings are subject to regulation by the FERC. APCo’s total billings from AEPSC were $313 million and $295 million for the years ended December 31, 2021 and 2020, respectively.
15.  PROPERTY, PLANT AND EQUIPMENT

Depreciation

APCo provides for depreciation of Utility Plant, on a straight-line basis over the estimated useful lives of property, generally using composite rates by functional class. The following table provides total regulated annual composite depreciation rates by functional class:
YearOther ProductionSteamHydroTransmissionDistributionGeneral
(in percentages)
2021
2.63.65.92.13.58.5
2020
2.63.43.02.23.77.8

The composite depreciation rate generally includes a component for non-ARO removal costs, which is credited to accumulated depreciation on the balance sheets. Actual removal costs incurred are charged to accumulated depreciation.

Asset Retirement Obligations

APCo records ARO in accordance with the accounting guidance for “Asset Retirement and Environmental Obligations” for legal obligations for asbestos removal and for the retirement of certain ash disposal facilities and certain coal-mining facilities. APCo has identified, but not recognized, ARO liabilities related to electric transmission and distribution assets as a result of certain easements on property on which assets are owned. Generally, such easements are perpetual and require only the retirement and removal of assets upon the cessation of the property’s use. The retirement obligation is not estimable for such easements since APCo plans to use its facilities indefinitely. The retirement obligation would only be recognized if and when APCo abandons or ceases the use of specific easements, which is not expected.

In 2020, Virginia’s Governor signed House Bill 443 (HB 443) requiring APCo to close certain ash disposal units at the retired Glen Lyn Station by removal of all coal combustion material. In June 2020, APCo recorded a revision to increase estimated Glen Lyn Station ash disposal ARO liabilities by $199 million due to the enactment of House Bill 443. In June 2021, management completed fully designed and costed project plans for the Glen Lyn Station site and increased ash disposal ARO liabilities by an additional $79 million. House Bill 443 provides for the recovery of all costs associated with closure by removal through the Virginia environmental rate adjustment clause. APCo is permitted to record carrying costs on the unrecovered balance of closure costs as a weighted-average cost of capital approved by the Virginia SCC. The legislation provides for regulatory recovery of these costs.

The following is a reconciliation of the 2021 and 2020 aggregate carrying amounts of ARO:
YearARO at January 1,Accretion ExpenseLiabilities SettledRevisions in Cash Flow Estimates (a)ARO at December 31,
(in millions)
2021$313.1 $13.7 $(6.9)$84.7 $404.6 (b)(c)
2020111.1 8.9 (7.8)200.9 313.1 (b)(c)

(a)Unless discussed above, primarily related to ash ponds, landfills and mine reclamation, generally due to changes in estimated closure area, volumes and/or unit costs.
(b)Includes ARO related to ash disposal facilities.
(c)Includes ARO related to asbestos removal.
16. REVENUE FROM CONTRACTS WITH CUSTOMERS

Disaggregated Revenues from Contracts with Customers
The tables below represent revenues from contracts with customers, net of respective provisions for refund, by type of revenue for APCo:

Years Ended December 31,
20212020
(in millions)
Retail Revenues:
Residential Revenues$1,378.3 $1,273.0 
Commercial Revenues555.8 526.9 
Industrial Revenues (a)583.7 563.9 
Other Retail Revenues70.7 68.9 
Total Retail Revenues2,588.5 2,432.7 
Wholesale Revenues:
Generation Revenues (b)342.7 247.1 
Transmission Revenues (a)128.8 130.9 
Total Wholesale Revenues
471.5 378.0 
Other Revenues from Contracts with Customers (a)
69.9 59.2 
Total Revenues from Contracts with Customers
3,129.9 2,869.9 
Other Revenues:
Alternative Revenues (a)12.3 (13.0)
Other Revenues(0.2)0.3 
Total Other Revenues12.1 (12.7)
Total Operating Revenues$3,142.0 $2,857.2 

(a)Amounts include affiliated and nonaffiliated revenues.
(b)Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $129 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial.
Performance Obligations

APCo has performance obligations as part of its normal course of business. A performance obligation is a promise to transfer a distinct good or service, or a series of distinct goods or services that are substantially the same and have the same pattern of transfer to a customer. The invoice practical expedient within the accounting guidance for “Revenue from Contracts with Customers” allows for the recognition of revenue from performance obligations in the amount of consideration to which there is a right to invoice the customer and when the amount for which there is a right to invoice corresponds directly to the value transferred to the customer.

The purpose of the invoice practical expedient is to depict an entity’s measure of progress toward completion of the performance obligation within a contract and can only be applied to performance obligations that are satisfied over time and when the invoice is representative of services provided to date. APCo elected to apply the invoice practical expedient to recognize revenue for performance obligations satisfied over time as the invoices from the respective revenue streams are representative of services or goods provided to date to the customer. Performance obligations for APCo are summarized as follows:

Retail Revenues

APCo has performance obligations to generate, transmit and distribute electricity for sale to rate-regulated retail customers. The performance obligation to deliver electricity is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Revenues are variable as they are subject to the customer’s usage requirements.

Rate-regulated retail customers typically have the right to discontinue receiving service at will, therefore these contracts between APCo and their customers for rate-regulated services are generally limited to the services requested and received to date for such arrangements. Retail customers are generally billed on a monthly basis, and payment is typically due within 15 to 20 days after the issuance of the invoice.

Wholesale Revenues - Generation

APCo has performance obligations to sell electricity to wholesale customers from generation assets in PJM. The performance obligation to deliver electricity from generation assets is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Wholesale generation revenues are variable as they are subject to the customer’s usage requirements.

APCo also has performance obligations to stand ready in order to promote grid reliability. Stand ready services are sold into PJM’s RPM capacity market. RPM entails a base auction and at least three incremental auctions for a specific PJM delivery year, with the incremental auctions spanning three years. The performance obligation to stand ready is satisfied over time and the consideration for which is variable until the occurrence of the final incremental auction, at which point the performance obligation becomes fixed.

Payments from the RTO for stand ready services are typically received within one week from the issuance of the invoice, which is typically issued weekly. Gross margin resulting from generation sales are primarily subject to margin sharing agreements with customers and vary by state, where the revenues are reflected gross in the disaggregated revenues table above.

APCo has a performance obligation to supply wholesale electricity to KGPCo through a PPA. The FERC regulates the cost-based wholesale power transactions between APCo and KGPCo. The purchased power agreement includes a component for the recovery of transmission costs under the FERC OATT. The transmission cost component of purchased power is cost-based and regulated by the Tennessee Regulatory Authority. APCo’s performance obligation under the purchased power agreement is satisfied over time as KGPCo simultaneously receives and
consumes the wholesale electricity. APCo’s revenues from the purchased power agreement are presented within the Generation Revenues line in the disaggregated revenues table above.

Wholesale Revenues - Transmission

APCo has performance obligations to transmit electricity to wholesale customers through assets owned and operated. The performance obligation to provide transmission services in PJM encompass a time frame greater than a year, where the performance obligation within each RTO is partially fixed for a period of one year or less. Payments from the RTO for transmission services are typically received within one week from the issuance of the invoice, which is issued weekly for PJM.

APCo collects revenues through transmission formula rates. The FERC-approved rates establish the annual transmission revenue requirement (ATRR) and transmission service rates for transmission owners. The formula rates establish rates for a one year period and also include a true-up calculation for the prior year’s billings, allowing for over/under-recovery of the transmission owner’s ATRR. The annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations,” and are therefore presented as such in the disaggregated revenues table above.

The AEP East Companies are parties to the TA, which defines how transmission costs are allocated among the AEP East Companies on a 12-month average coincident peak basis. Affiliate revenues as a result of the respective TA are reflected as Transmission Revenues in the disaggregated revenues table above.

Fixed Performance Obligations

The following table represents the remaining fixed performance obligations satisfied over time as of December 31, 2021. Fixed performance obligations primarily include wholesale transmission services, electricity sales for fixed amounts of energy and stand ready services into PJM’s RPM market. The amounts shown in the table below include affiliated and nonaffiliated revenues.

20222023-20242025-2026After 2026Total
(in millions)
$201.5 $32.2 $23.2 $11.6 $268.5 

Contract Assets and Liabilities

Contract assets are recognized when APCo has a right to consideration that is conditional upon the occurrence of an event other than the passage of time, such as future performance under a contract. APCo did not have any material contract assets as of December 31, 2021 and 2020.

When APCo receives consideration, or such consideration is unconditionally due from a customer prior to transferring goods or services to the customer under the terms of a sales contract, they recognize a contract liability on the balance sheets in the amount of that consideration. Revenue for such consideration is subsequently recognized in the period or periods in which the remaining performance obligations in the contract are satisfied. APCo’s contract liabilities typically arise from services provided under joint use agreements for utility poles. APCo did not have any material contract liabilities as of December 31, 2021 and 2020.

Accounts Receivable from Contracts with Customers

Accounts receivable from contracts with customers are presented on APCo’s balance sheets within the Customer Accounts Receivable line item. APCo’s balances for receivables from contracts that are not recognized in accordance with the accounting guidance for “Revenue from Contracts with Customers” included in Customer
Accounts Receivable were not material as of December 31, 2021 and 2020. See “Securitized Accounts Receivable - AEP Credit” section of Note 13 for additional information.

The amount of affiliated accounts receivable from contracts with customers included in Accounts Receivable from Associated Companies on APCo’s balance sheets were $118 million and $53 million, as of December 31, 2021 and 2020.

Contract Costs

Contract costs to obtain or fulfill a contract for APCo are accounted for under the guidance for “Other Assets and Deferred Costs” and presented as a single asset and are neither bifurcated nor reclassified between current assets and deferred debits on the balance sheets. Contract costs to acquire a contract are amortized in a manner consistent with the transfer of goods or services to the customer in Operation Expenses on the income statements. APCo did not have material contract costs as of December 31, 2021 and 2020.
17. FERC ORDER NO. 784-A

On July 18, 2013, the FERC issued Order No. 784 that revised certain aspects of the accounting and reporting requirements under the Uniform System of Accounts related to energy storage accounts. Due to software limitations, the newly adopted and revised schedules in the FERC forms that would contain the energy storage accounts are not available to filers of the forms for use as of the effective date. Utilities with energy storage assets must use the existing schedules in the FERC Forms to report energy storage assets pending availability of the new and revised schedules. FERC directed filers to submit the requested energy storage information as part of pages 122-123.

The following table presents APCo’s energy storage operations for small plants for the years ended December 31, 2021 and 2020, as required by FERC Order No. 784:

OperationMaintenance
ProjectFunctionalProjectProject CostsExpensesExpenses
NameClassificationLocationAccountAmountAccountAmountAccountAmount (a)
(dollars in millions)
Year Ended December 31, 2021
Balls Gap StationDistributionBalls Gap, WV363$5.4 562$592$
Byllesby Hydro PlantGenerationIvanhoe, Virginia3485.7 562592
Chemical StationTransmissionN. Charleston, WV351— 562592
Year Ended December 31, 2020
Balls Gap StationDistributionBalls Gap, WV363$5.4 562$592$
Chemical StationTransmissionN. Charleston, WV351— 562592

(a) This amount would have been recorded in Account 592.2 in accordance with FERC Order No. 784.


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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
64,188
4,206,754
898,206
5,040,772
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3,438,622
1,731,328
5,169,950
3
Preceding Quarter/Year to Date Changes in Fair Value
36
8,050,598
8,050,562
4
Total (lines 2 and 3)
36
4,611,976
1,731,328
2,880,612
369,732,667
372,613,279
5
Balance of Account 219 at End of Preceding Quarter/Year
64,224
8,818,730
833,122
7,921,384
6
Balance of Account 219 at Beginning of Current Year
64,224
8,818,730
833,122
7,921,384
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
4,891,938
8,337,016
3,445,078
8
Current Quarter/Year to Date Changes in Fair Value
36
13,012,772
13,012,736
9
Total (lines 7 and 8)
36
8,120,834
8,337,016
16,457,814
348,937,055
365,394,869
10
Balance of Account 219 at End of Current Quarter/Year
64,260
16,939,564
7,503,894
24,379,198


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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)
14,952,499,535
14,952,499,535
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
102,541,648.90
102,541,648.90
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
1,342,813,476
1,342,813,476
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
8
UtilityPlantInServiceClassifiedAndUnclassified
Total (3 thru 7)
16,397,854,660
16,397,854,660
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
3,144,691.00
3,144,691.00
11
ConstructionWorkInProgress
Construction Work in Progress
471,403,315
471,403,315
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
181,679.00
181,679.00
13
UtilityPlantAndConstructionWorkInProgress
Total Utility Plant (8 thru 12)
16,872,584,345
16,872,584,345
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
5,765,578,075
5,765,578,075
15
UtilityPlantNet
Net Utility Plant (13 less 14)
11,107,006,270
11,107,006,270
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
5,627,412,008
5,627,412,008
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
137,988,536
137,988,536
22
DepreciationAmortizationAndDepletionUtilityPlantInService
Total in Service (18 thru 21)
5,765,400,544
5,765,400,544
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
4,147.90
4,147.90
29
AmortizationUtilityPlantHeldForFutureUse
Amortization
30
DepreciationAndAmortizationUtilityPlantHeldForFutureUse
Total Held for Future Use (28 & 29)
4,148
4,148
31
AbandonmentOfLeases
Abandonment of Leases (Natural Gas)
32
AmortizationOfPlantAcquisitionAdjustment
Amortization of Plant Acquisition Adjustment
181,679.00
181,679.00
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Total Accum Prov (equals 14) (22,26,30,31,32)
5,765,578,075
5,765,578,075


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
  1. Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent.
  2. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.
Description of item
(a)
Balance Beginning of Year
(b)
Changes during Year Additions
(c)
Changes during Year Amortization
(d)
Changes during Year Other Reductions (Explain in a footnote)
(e)
Balance End of Year
(f)
1
Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2
Fabrication
3
Nuclear Materials
4
Allowance for Funds Used during Construction
5
(Other Overhead Construction Costs, provide details in footnote)
6
SUBTOTAL (Total 2 thru 5)
7
Nuclear Fuel Materials and Assemblies
8
In Stock (120.2)
9
In Reactor (120.3)
10
SUBTOTAL (Total 8 & 9)
11
Spent Nuclear Fuel (120.4)
12
Nuclear Fuel Under Capital Leases (120.6)
13
(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14
TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15
Estimated Net Salvage Value of Nuclear Materials in Line 9
16
Estimated Net Salvage Value of Nuclear Materials in Line 11
17
Est Net Salvage Value of Nuclear Materials in Chemical Processing
18
Nuclear Materials held for Sale (157)
19
Uranium
20
Plutonium
21
Other (Provide details in footnote)
22
TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
  1. Report below the original cost of electric plant in service according to the prescribed accounts.
  2. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric.
  3. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year.
  4. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments.
  5. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
  6. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year.
  7. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications.
  8. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages.
  9. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Additions
(c)
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at End of Year
(g)
1
1. INTANGIBLE PLANT
2
(301) Organization
133,394
133,394
3
(302) Franchise and Consents
15,259,243
1,791
477
15,260,557
4
(303) Miscellaneous Intangible Plant
233,893,075
45,456,779
14,868,256
264,481,598
5
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)
249,285,713
45,458,570
14,868,733
279,875,549
6
2. PRODUCTION PLANT
7
A. Steam Production Plant
8
(310) Land and Land Rights
12,363,468
12,363,468
9
(311) Structures and Improvements
400,823,516
3,324,684
1,327,754
0
402,820,446
10
(312) Boiler Plant Equipment
4,405,110,291
37,742,644
19,349,074
4,423,503,861
11
(313) Engines and Engine-Driven Generators
12
(314) Turbogenerator Units
453,352,114
4,241,758
3,875,562
453,718,309
13
(315) Accessory Electric Equipment
181,486,230
2,240,560
1,014,835
182,711,955
14
(316) Misc. Power Plant Equipment
81,660,838
5,655,568
550,279
65,865
86,700,262
15
(317) Asset Retirement Costs for Steam Production
90,810,389
6,115,057
96,925,446
16
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
5,625,606,846
59,320,271
26,117,505
65,865
5,658,743,747
17
B. Nuclear Production Plant
18
(320) Land and Land Rights
19
(321) Structures and Improvements
20
(322) Reactor Plant Equipment
21
(323) Turbogenerator Units
22
(324) Accessory Electric Equipment
23
(325) Misc. Power Plant Equipment
24
(326) Asset Retirement Costs for Nuclear Production
25
TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26
C. Hydraulic Production Plant
27
(330) Land and Land Rights
9,800,639
174
9,800,813
28
(331) Structures and Improvements
30,599,801
239,785
30,839,586
29
(332) Reservoirs, Dams, and Waterways
82,877,994
2,950,589
464,154
85,364,429
30
(333) Water Wheels, Turbines, and Generators
113,742,454
3,626,658
117,425
117,251,688
31
(334) Accessory Electric Equipment
25,971,183
621,129
272,069
26,320,244
32
(335) Misc. Power Plant Equipment
23,005,977
225,648
23,231,625
33
(336) Roads, Railroads, and Bridges
1,241,854
1,241,854
34
(337) Asset Retirement Costs for Hydraulic Production
2,682,604
2,682,604
35
TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
289,922,507
7,663,810
853,648
174
296,732,843
36
D. Other Production Plant
37
(340) Land and Land Rights
3,196,932
3,196,932
38
(341) Structures and Improvements
50,430,382
1,513,778
146,364
51,797,796
39
(342) Fuel Holders, Products, and Accessories
26,968,819
466,127
412,199
27,022,746
40
(343) Prime Movers
41
(344) Generators
508,845,078
8,813,791
748,956
516,909,913
42
(345) Accessory Electric Equipment
48,079,497
287,034
180,647
48,185,884
43
(346) Misc. Power Plant Equipment
31,688,645
2,523,736
1,879,243
32,333,138
44
(347) Asset Retirement Costs for Other Production
44.1
(348) Energy Storage Equipment - Production
5,726,249
5,726,249
45
TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
674,935,601
13,604,467
3,367,409
685,172,659
46
TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
6,590,464,954
80,588,548
30,338,562
65,691
6,640,649,250
47
3. Transmission Plant
48
(350) Land and Land Rights
201,475,187
14,626,949
260,858
54,640
215,895,917
48.1
(351) Energy Storage Equipment - Transmission
49
(352) Structures and Improvements
118,187,918
55,729,167
1,424,127
(a)
172,492,959
50
(353) Station Equipment
1,854,529,371
228,260,255
23,083,836
207,998
2,059,913,788
51
(354) Towers and Fixtures
508,792,476
7,979,631
2,203,442
514,568,666
52
(355) Poles and Fixtures
482,905,560
53,838,772
9,951,510
526,792,822
53
(356) Overhead Conductors and Devices
699,258,823
90,679,600
4,925,660
785,012,763
54
(357) Underground Conduit
10,132,518
7,267,560
17,400,078
55
(358) Underground Conductors and Devices
23,589,203
5,171,662
5,886
28,754,978
56
(359) Roads and Trails
57
(359.1) Asset Retirement Costs for Transmission Plant
58
TOTAL Transmission Plant (Enter Total of lines 48 thru 57)
3,898,871,056
463,553,597
41,855,319
262,638
4,320,831,972
59
4. Distribution Plant
60
(360) Land and Land Rights
72,214,660
1,913,216
114,206
536,487
74,550,158
61
(361) Structures and Improvements
62,236,280
7,274,596
510,231
69,000,645
62
(362) Station Equipment
671,260,440
40,255,872
6,439,452
199,721
704,877,139
63
(363) Energy Storage Equipment – Distribution
5,411,171
91,756
155,807
8,277
5,338,844
64
(364) Poles, Towers, and Fixtures
838,857,178
39,822,649
7,000,805
871,679,023
65
(365) Overhead Conductors and Devices
1,074,969,935
97,214,805
7,692,722
1,164,492,018
66
(366) Underground Conduit
140,184,194
4,440,247
91,270
144,533,172
67
(367) Underground Conductors and Devices
315,161,218
9,914,143
779,810
324,295,551
68
(368) Line Transformers
633,640,774
25,769,510
8,534,890
650,875,394
69
(369) Services
362,588,824
13,953,554
2,446,074
374,096,304
70
(370) Meters
192,666,444
25,584,855
15,926,420
202,324,879
71
(371) Installations on Customer Premises
62,434,434
4,362,955
2,816,396
63,980,992
72
(372) Leased Property on Customer Premises
771
771
73
(373) Street Lighting and Signal Systems
30,967,525
1,544,455
441,166
32,070,814
74
(374) Asset Retirement Costs for Distribution Plant
3,069
3,069
75
TOTAL Distribution Plant (Enter Total of lines 60 thru 74)
4,462,596,917
272,142,614
52,949,248
328,489
4,682,118,772
76
5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77
(380) Land and Land Rights
78
(381) Structures and Improvements
79
(382) Computer Hardware
80
(383) Computer Software
81
(384) Communication Equipment
82
(385) Miscellaneous Regional Transmission and Market Operation Plant
83
(386) Asset Retirement Costs for Regional Transmission and Market Oper
84
TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85
6. General Plant
86
(389) Land and Land Rights
15,224,417
779,440
16,003,857
87
(390) Structures and Improvements
153,227,387
2,350,165
540,510
155,037,041
88
(391) Office Furniture and Equipment
11,830,299
336,363
142,768
12,023,894
89
(392) Transportation Equipment
8,674
8,674
90
(393) Stores Equipment
2,046,596
29,332
2,075,929
91
(394) Tools, Shop and Garage Equipment
40,150,710
1,429,505
41,580,214
92
(395) Laboratory Equipment
3,096,136
255,052
278,274
3,072,914
93
(396) Power Operated Equipment
132,662
132,662
94
(397) Communication Equipment
96,117,540
38,144,353
1,832,665
132,429,228
95
(398) Miscellaneous Equipment
7,590,800
527,730
77,434
65,865
8,106,961
96
SUBTOTAL (Enter Total of lines 86 thru 95)
329,292,558
43,984,603
2,871,651
65,865
370,471,374
97
(399) Other Tangible Property
98
(399.1) Asset Retirement Costs for General Plant
1,204,129
161,967
1,366,095
99
TOTAL General Plant (Enter Total of lines 96, 97, and 98)
330,496,686
44,146,570
2,871,651
65,865
371,837,469
100
TOTAL (Accounts 101 and 106)
15,531,715,326
905,889,899
142,883,514
591,301
16,295,313,011
101
(102) Electric Plant Purchased (See Instr. 8)
102
(Less) (102) Electric Plant Sold (See Instr. 8)
103
(103) Experimental Plant Unclassified
104
TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)
15,531,715,326
905,889,899
142,883,514
591,301
16,295,313,011


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: StructuresAndImprovementsTransmissionPlant
The investment and related accumulated depreciation in Generation Step-Up Units (GSUs) in plant accounts 352-353 included in APCo's generation formula rates are identified by a query of the plant accounting system

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.
LesseeName
Name of Lessee
(a)
IndicationOfAssociatedCompany
* (Designation of Associated Company)
(b)
LeaseDescription
Description of Property Leased
(c)
CommissionAuthorization
Commission Authorization
(d)
ExpirationDateOfLease
Expiration Date of Lease
(e)
ElectricPlantLeasedToOthers
Balance at End of Year
(f)
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
TOTAL


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
  1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use.
  2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.
ElectricPlantHeldForFutureUseDescription
Description and Location of Property
(a)
ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Date Originally Included in This Account
(b)
ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Date Expected to be used in Utility Service
(c)
ElectricPlantHeldForFutureUse
Balance at End of Year
(d)
1 Land and Rights:
2
Amos-Gavin 765KV Comm Solvents Tract Land, WV (2639)
09/23/1974
256,070.00
3
John E. Amos Fly Ash Area 3, Putnam Co., WV - approx 132.65 acres of land (0745)
06/30/1973
287,900.66
4
Shadwell 69KV Substation, Roanoke County, VA 10.637 acres (7662)
08/01/2009
12/31/2022
431,124.17
5
Sheridan 69KV Substation, Lincoln County, WV 4.947 acres (2041)
11/01/2015
12/31/2022
327,041.50
6
Items under $250,000
1,842,554.27
21 Other Property:
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 TOTAL
3,144,691


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
  1. Report below descriptions and balances at end of year of projects in process of construction (107).
  2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts).
  3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.
ConstructionWorkInProgressProjectDescription
Description of Project
(a)
ConstructionWorkInProgress
Construction work in progress - Electric (Account 107)
(b)
1
AM CCR/ELG Compliance
43,630,657
2
Amos 1&2 DSI Project
2,340,518
3
AMU2 Air Heater Basket Replace
1,931,992
4
APCO - T Work Supplemental
1,166,242
5
APCo AMI Project VA
11,904,524
6
APCO AMI Project WV
9,929,265
7
APCo D (Floyd-Stuart Area)
1,800,265
8
APCo D Work (Supplemental)
2,927,933
9
APCO Distr Pre Eng Parent
4,966,372
10
APCo DISTR Work
3,081,856
11
APCo Distribution Work
3,457,862
12
APCO Next Generation Radio Sys
14,070,199
13
APCo T (Station)
1,529,770
14
APCo T Work
12,857,374
15
APCo T Work (Supplemental)
2,143,584
16
APCo T-BlnktProj Under $3M
2,909,516
17
APCO Trans Pre Eng Parent
13,013,528
18
APCo Transmission Work
8,139,980
19
APCo VA Major Eq/ Spares-Trans
4,056,731
20
APCO: 2020 - 2022 RBB Grayson
8,983,858
21
APCO: 2020-2021 MW Upgrades
1,508,080
22
APCO: 2021 - 2023 RBB LOGAN &
3,052,352
23
APCO-D
4,091,476
24
APCo-D Service Restoration Blk
1,667,233
25
APCo-D Small Cap Adds Blkt
1,454,077
26
APCO-D Telecom
1,272,574
27
APCo-D Third Party Work Blkt
1,880,559
28
APCo-T Work
1,618,673
29
APCo-T Work 1
1,773,536
30
APCO-Tranco Line Rebuild-T
2,275,019
31
Berry Hill Station
2,385,013
32
CIS-Common Deployment-APC D
1,193,067
33
CLH 3 Tailrace Disolved Oxygen
1,089,241
34
CLH 4 Tailrace Disolved Oxygen
1,089,241
35
Corp Prgrm Billing - APCO Tran
2,381,824
36
D/AP/Capital Blanket - APCo
1,744,799
37
D/AP/Distribution Work
8,594,082
38
MT CI SCR CATALYST 2ND LAYER
1,315,490
39
MT ELG/CCR Compliance
26,525,517
40
MT HP TURBINE CP REFURBISH
2,890,247
41
NIH RELICENSE NIAGARA HYDRO
1,491,701
42
Purchase New APCO HDQ Building
3,744,636
43
Roanoke, VA TOC
86,972,799
44
SS-CI-APCo-D GEN PLT
4,669,975
45
SS-CI-APCo-T GEN PLT
1,241,907
46
T/AP/Capital Blanket - APCo
3,738,868
47
Ds-Ap-Virg-Ai Recloser Repl
1,643,775
48
T/AP/Charleston to Roanoke Tel
1,235,766
49
T/AP/CrningGls-Rdgewy69kv:Relo
4,203,842
50
T/AP/Danville - Martinsville T
1,869,999
51
T/AP/NERC Physical Security
16,605,575
52
T/AP/Roanoke to Kingsport Tele
2,884,691
53
T/AP/Sheridan Trans CI
1,428,168
54
Teays Valley SC Land Purchase
1,183,128
55
U3 IP ROTOR & CYLINDER REFURBI
2,183,702
56
Unit 2 Turbine Rotors A & B
2,811,644
57
Ds-AP-WVirg-AI Recloser Repl
2,034,716
58
Wo 020749999
3,920,666
59
WS-CI-APCo-G PPB
29,576,033
60
Ed-Ci-Apco-D Ast Imp
25,198,994
61
Ed-Ci-Apco-D Cust Serv
1,854,744
62
Forestry - APCo-T
1,133,619
63
GT1A Hot Gas Path
1,944,901
64
GT1B Hot Gas Path
1,606,722
65
John Vaughan Truck Garage
3,378,768
66
Other Minor Projects under $1,000,000
50,368,652
43 Total
471,403,315


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
  1. Explain in a footnote any important adjustments during year.
  2. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property.
  3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications.
  4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.
Item
(a)
Total (c + d + e)
(b)
Electric Plant in Service
(c)
Electric Plant Held for Future Use
(d)
Electric Plant Leased To Others
(e)
Section A. Balances and Changes During Year
1
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance Beginning of Year
5,301,060,976
5,301,065,124
4,148
2
Depreciation Provisions for Year, Charged to
3
DepreciationExpenseExcludingAdjustments
(403) Depreciation Expense
498,113,773
498,113,773
4
DepreciationExpenseForAssetRetirementCosts
(403.1) Depreciation Expense for Asset Retirement Costs
3,452,247
3,452,247
5
ExpensesOfElectricPlantLeasedToOthers
(413) Exp. of Elec. Plt. Leas. to Others
6
TransportationExpensesClearing
Transportation Expenses-Clearing
7
OtherClearingAccounts
Other Clearing Accounts
690,473
690,473
8
OtherAccounts
Other Accounts (Specify, details in footnote):
9.1
Other Accounts (Specify, details in footnote):
350,671
(a)
350,671
10
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)
501,905,823
501,905,823
11
Net Charges for Plant Retired:
12
BookCostOfRetiredPlant
Book Cost of Plant Retired
128,014,780
128,014,780
13
CostOfRemovalOfPlant
Cost of Removal
60,429,540
(b)
60,429,540
14
SalvageValueOfRetiredPlant
Salvage (Credit)
12,885,382
(c)
12,885,382
15
NetChargesForRetiredPlant
TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)
175,558,938
175,558,938
16
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote):
17.1
Other Debit or Cr. Items (Describe, details in footnote):
18
BookCostOfAssetRetirementCosts
Book Cost or Asset Retirement Costs Retired
19
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)
5,627,407,860
5,627,412,008
4,148
Section B. Balances at End of Year According to Functional Classification
20
AccumulatedDepreciationSteamProduction
Steam Production
2,694,240,440
2,694,240,440
21
AccumulatedDepreciationNuclearProduction
Nuclear Production
22
AccumulatedDepreciationHydraulicProductionConventional
Hydraulic Production-Conventional
73,678,460
73,678,460
23
AccumulatedDepreciationHydraulicProductionPumpedStorage
Hydraulic Production-Pumped Storage
92,462,599
92,462,599
24
AccumulatedDepreciationOtherProduction
Other Production
248,613,514
248,613,514
25
AccumulatedDepreciationTransmission
Transmission
799,298,358
799,302,506
4,148
26
AccumulatedDepreciationDistribution
Distribution
1,621,676,367
1,621,676,367
27
AccumulatedDepreciationRegionalTransmissionAndMarketOperation
Regional Transmission and Market Operation
28
AccumulatedDepreciationGeneral
General
97,438,122
97,438,122
29
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28)
5,627,407,860
5,627,412,008
4,148


FOOTNOTE DATA

(a) Concept: OtherAccounts
FERC Generation Wholesale Amortization-Clinch River ARO -32,124
KGPCo Wholesale Amortiation-Clinch River ARO -50,700
Generation Wholesale Expense-1823377 VA Plants -103,875
KGPCo Wholesale Expense-1823377 VA Plants -163,972
-350,671
(b) Concept: CostOfRemovalOfPlant
Includes $10,938,351 of removal cost in retirement work in progress (RWIP).
(c) Concept: SalvageValueOfRetiredPlant
Includes ($7,726,052) of salvage in retirement work in progress (RWIP).

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
  1. Report below investments in Account 123.1, Investments in Subsidiary Companies.
  2. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal.
  3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1.
  4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge.
  5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number.
  6. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year.
  7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f).
  8. Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.
DescriptionOfInvestmentsInSubsidiaryCompanies
Description of Investment
(a)
DateOfAcquisitionInvestmentsInSubsidiaryCompanies
Date Acquired
(b)
DateOfMaturityInvestmentsInSubsidiaryCompanies
Date of Maturity
(c)
InvestmentInSubsidiaryCompanies
Amount of Investment at Beginning of Year
(d)
EquityInEarningsOfSubsidiaryCompanies
Equity in Subsidiary Earnings of Year
(e)
InterestAndDividendRevenueFromInvestments
Revenues for Year
(f)
InvestmentInSubsidiaryCompanies
Amount of Investment at End of Year
(g)
InvestmentGainLossOnDisplosal
Gain or Loss from Investment Disposed of
(h)
1
Central Appalachian Coal Company
2
SEC File 70-1841, 6-18-48
3
SEC File 70-2749, 8.14-50
4
3,000 shares common stock
3,000
3,000
5
Capital Contributions Central Appalachian Coal Company
10/09/1990
449,990
449,990
6
Undistributed earnings/losses and dividends - Central Appalachian Coal
194,057
194,057
7
Central Coal Company
8
SEC File 70-1770, 4-30-48
9
1,500 shares common stock
1,500
1,500
10
Capital Contributions Central Coal Company
602,368
602,368
11
Investment in Central Coal Company
12
Southern Appalachian Coal Company
13
SEC File 70-5144, 3-23-72
14
6,950 shares common stock
6,950
6,950
15
Capital Contributions - Southern Appalachian Coal Company
16
Investment in Premium on Common Stock
900,000
900,000
17
Undistributed earnings/losses and dividends - Southern Appalachian Coal Company
690,462
690,462
18
Cedar Coal Company
19
SEC File 70-5470, 4-30-74
20
2,000 shares common stock
04/10/1974
200,000
200,000
21
Capital Contributions - Cedar Coal
4,868,403
4,868,403
22
Investment in Subsidiary AOCI
175,807
616,541
792,348
23
Undistributed earnings/losses and dividends - Cedar Coal Company
2,483,074
2,483,074
42
Total Cost of Account 123.1 $
Total
5,257,849
616,541
4,641,308


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
MATERIALS AND SUPPLIES
  1. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material.
  2. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Balance End of Year
(c)
Department or Departments which Use Material
(d)
1
Fuel Stock (Account 151)
182,954,925
61,380,905
Electric
2
Fuel Stock Expenses Undistributed (Account 152)
10,651,652
5,704,904
Electric
3
Residuals and Extracted Products (Account 153)
4,821
6,791
Electric
4
Plant Materials and Operating Supplies (Account 154)
5
Assigned to - Construction (Estimated)
52,071,664
63,761,224
Electric
6
Assigned to - Operations and Maintenance
7
Production Plant (Estimated)
45,758,604
43,429,835
Electric
8
Transmission Plant (Estimated)
67,643
220,485
Electric
9
Distribution Plant (Estimated)
1,009,953
1,249,262
Electric
10
Regional Transmission and Market Operation Plant (Estimated)
11
Assigned to - Other (provide details in footnote)
(a)
297,940
(b)
393,051
Electric
12
TOTAL Account 154 (Enter Total of lines 5 thru 11)
99,205,804
109,053,857
13
Merchandise (Account 155)
14
Other Materials and Supplies (Account 156)
15
Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16
Stores Expense Undistributed (Account 163)
17
18
19
20
TOTAL Materials and Supplies
292,817,202
176,146,456


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesOther
Assigned to - Other includes Customer Account, Administrative, and General Expenses.
(b) Concept: PlantMaterialsAndOperatingSuppliesOther
Assigned to - Other includes Customer Account, Administrative, and General Expenses.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
SO2 Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
1,103,940
22,346,849
185,894
185,894
185,897
4,207,923
5,869,548
22,346,849
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
4,404
162,274
166,678
5
Returned by EPA
6
7
8
Purchases/Transfers:
9
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
18,860
228,367
18,860
228,367
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
Consent Decree Surrenders
149,133
149,133
23
24
25
26
27
28
Total
149,133
149,133
29
Balance-End of Year
1,089,484
(a)
22,118,482
36,761
185,894
185,894
4,370,197
5,868,230
22,118,482
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
1,746
1,746
1,746
1,746
95,375
102,359
37
Add: Withheld by EPA
3,491
3,491
38
Deduct: Returned by EPA
39
Cost of Sales
1,746
1,745
3,491
40
Balance-End of Year
1,746
1,746
1,746
97,121
102,359
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: AllowanceInventory
NOX has no book value associated with the quantity. $75,200 is for 10,010 units of CO2, that was purchased in December 2020.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
NOx Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
75,371
75,200
22,058
22,058
22,055
141,542
75,200
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
3,182
4,929
4,929
4,929
17,969
5
Returned by EPA
6
7
8
Purchases/Transfers:
9
Chicago Climate Exchange
150,000
1,329,300
150,000
1,329,300
10
Other
11
12
13
14
15
Total
150,000
1,329,300
150,000
1,329,300
16
17
Relinquished During Year:
18
Charges to Account 509
108,668
728,776
108,668
728,776
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
Wolverine Power Supply Cooperative, Inc.
1,120
1,120
23
24
25
26
27
28
Total
1,120
1,120
29
Balance-End of Year
112,401
(a)
675,724
17,129
17,129
17,129
163,788
675,724
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: AllowanceInventory
NOX has no book value associated with the quantity. $75,200 is for 10,010 units of CO2, that was purchased in December 2020.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfExtraordinaryPropertyLoss
Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).]
(a)
ExtraordinaryPropertyLossesNotYetRecognized
Total Amount of Loss
(b)
ExtraordinaryPropertyLossesRecognized
Losses Recognized During Year
(c)
ExtraordinaryPropertyLossesWrittenOffAccountCharged
Account Charged
(d)
ExtraordinaryPropertyLossesWrittenOff
Amount
(e)
ExtraordinaryPropertyLosses
Balance at End of Year
(f)
1
(a)
Bluefield Office Building
365,177
6,087
2
(b)
Glen Lyn Unit 6
5,703,621
125,660
4,232,368
3
(c)
Kanawha Plant
27,432,795
1,091,892
20,564,098
4
(d)
Sporn Plant
10,478,046
458,519
7,779,589
5
(e)
Clinch River Plant Coal Assets
58,709,555
1,720,913
46,506,344
20 TOTAL
102,689,194
3,403,071
79,082,399


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfExtraordinaryPropertyLoss
Authorized by the West Virginia commission on April 10, 2006. Amortization period: April 2006 to March 2021.
(b) Concept: DescriptionOfExtraordinaryPropertyLoss
Authorized by the West Virginia commission on May 26, 2015. Amortization period: June 2015 to July 2032.
(c) Concept: DescriptionOfExtraordinaryPropertyLoss
Authorized by the West Virginia commission on May 26, 2015. Amortization period: June 2015 to July 2041.
(d) Concept: DescriptionOfExtraordinaryPropertyLoss
Authorized by the West Virginia commission on May 26, 2015. Amortization period: June 2015 to February 2040.
(e) Concept: DescriptionOfExtraordinaryPropertyLoss
Clinch River Units 1 & 2 were authorized by the West Virginia commission on May 26, 2015.
Amortization period: October 2015 to November 2052. Coal Blending Assets amortized through June 2048.
Clinch River Unit 3 was authorized by the West Virginia commission on May 26, 2015. Amortization period: June 2015 to January 2040.
The amortization period for all Clinch River units was updated to end in December 2040 by the West Virginia commission on February 27, 2019.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts
Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)]
(a)
UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized
Total Amount of Charges
(b)
UnrecoveredPlantAndRegulatoryStudyCostsRecognized
Costs Recognized During Year
(c)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged
Account Charged
(d)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff
Amount
(e)
UnrecoveredPlantAndRegulatoryStudyCosts
Balance at End of Year
(f)
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
TOTAL


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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
AE1-064
4,899
4,039
3
AE1-108
54,704
52,257
4
AE1-108
39,996
39,951
5
AE1-250
169,089
152,264
6
AE2-160
2,870
1,200
7
AF1-049
8,951
8,808
8
AF1-323
54,430
53,286
9
AF2-382
13,265
12,908
10
AG1-089
1,143
1,029
11
AG1-091
7,706
7,264
12
AG1-092
5,651
5,353
13
AG1-124
1,373
1,197
14
AG1-136
4,416
3,985
15
AG1-162
4,482
3,954
16
AG1-194
1,340
1,196
17
AG1-219
1,880
1,670
18
AG1-234
2,118
2,118
19
AG1-311
1,214
1,130
20
AG1-316
1,915
2,066
21
AG1-468
1,901
2,776
22
AG1-508
3,377
3,874
23
AG1-509
2,775
3,073
24
AG1-528
1,597
1,475
25
AG1-540
663
813
26
AG2-127
1,991
1,960
27
AG2-132
1,421
1,390
28
AG2-168
2,069
2,046
29
AG2-187
1,732
1,700
30
AG2-190
392
392
31
AG2-202
1,776
1,742
32
AG2-203
1,936
1,901
33
AG2-311
873
843
34
AG2-368
1,455
1,421
35
AG2-568
1,534
1,481
36
AG2-657
1,278
1,218
37
PJM - #AD1-017
24
519
38
PJM - #AD1-102
28,502
35,046
39
PJM - #AD2-022
166
40
PJM - #AD2-022
40,449
88,543
41
PJM - #AD2-178
9,053
38,753
42
PJM - #AD2-178
31
43
PJM - #AD2-179
32,903
40,002
44
PJM - #AD2-179
34
45
PJM - #AE1-121
2,917
17,733
46
PJM - #AE1-130
1,228
1,425
47
PJM - #AE1-176
22
48
PJM - #AE1-212
15,179
35,208
49
PJM - #AE1-250
2,171
2,377
50
PJM - #AE2-047
16,425
35,237
51
PJM - #AE2-047
57
52
PJM - #AE2-140
61,112
68,114
53
PJM - #AE2-140
369
54
PJM - #AE2-166
7,937
44,199
55
PJM - #AE2-166
70
56
PJM - #AE2-185
60
57
PJM - #AE2-280
154,449
141,255
58
PJM - #AE2-280
39
59
PJM - #AE2-280
63
60
PJM - #AE2-292
18
61
PJM - #AE2-326
2,771
3,752
62
PJM - #AF1-049
151
63
PJM - #AF1-323
95
64
PJM - #AF1-323
104
65
PJM - #AF2-105
261
66
PJM - #AF2-105
1,014
1,014
67
PJM - #AF2-106
375
68
PJM - #AF2-106
1,376
1,402
69
PJM - #AF2-107
133
70
PJM - #AF2-107
1,052
1,078
71
PJM - #AF2-220
219
72
PJM - #AF2-291
147
73
PJM - #AF2-291
764
790
74
PJM - #AF2-302
168
75
PJM - #AF2-302
884
810
76
PJM - #AF2-382
167
77
PJM - #AF2-382
2,340
2,218
78
PJM - #AG1-022
1,733
2,142
79
PJM - #AG1-089
1,483
2,196
80
PJM - #AG1-091
726
81
PJM - #AG1-092
772
82
PJM - #AG1-123
2,484
2,957
83
PJM - #AG1-124
1,453
1,846
84
PJM - #AG1-136
1,318
1,822
85
PJM - #AG1-155
1,677
2,577
86
PJM - #AG1-194
1,038
1,434
87
PJM - #AG1-219
1,784
2,273
88
PJM - #AG1-240
473
1,004
89
PJM - #AG1-311
1,603
2,296
90
PJM - #AG1-314
385
789
91
PJM - #AG1-426
1,374
1,916
92
PJM - #AG1-494
1,560
1,960
93
PJM - #AG1-528
1,641
2,358
94
PJM - AF1-173
5
95
PJM AC1-122 & 123
49
96
PJM AC2-123
2,353
8,817
20
Total
21
Generation Studies
39
Total
40 Grand Total


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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
Under Recovery of PJM True-Up
1,194,294
3,499,837
4,694,131
2
SFAS 112 Postemployment Benefits - Rate Order: WV PSC Case 14-1152-E-42T
13,535,266
161,408
427,503
13,269,171
3
Demand Side Management Under Recovery - Rate Order: WV Public Service Commission - Case No: 10-0261-E-GI - Case No: WV PSC Case 15-0301-E-GI
6,746,972
4,572,124
1,422,432
9,896,664
4
Unrealized Loss on Forward Commitments
5,235,279
15,628,050
14,230,672
3,837,901
5
Netting of Trading Activities related to Unrealized Gains/Losses on Forward Commitments between Regulated Assets/Liabilities
5,235,279
14,230,672
15,628,050
3,837,901
6
Environmental Compliance Costs - Rate Orders: VA Code Section 56-582B (vi) VASCCPUE-2005-00056 - Amortization Period: 01/2021 - 12/2023
196,781
65,594
131,187
7
Carrying Chgs-Capital Environmental Compliance Csts - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023
100,873
33,624
67,249
8
Capital Environmental Equity Costs - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023
12,017
4,006
8,011
9
Defd System Reliability Costs - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023
75,018
44,943
30,075
10
Equity Costs - Capital Reliability - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023
44,977
4,349
40,628
11
Defd Carrying Charges - Reliability Capital - Rate Orders: VA Code Section 56-582B (vi) VA SCC PUE-2005-00056 - Amortization Period: 01/2021 - 12/2023
54,445
19,734
74,179
12
Unrecovered Fuel Cost - VA
3,330,925
131,199,922
7,321,623
127,209,224
13
Unrecovered Fuel Cost - WV
4,263,215
94,936,489
26,530,749
72,668,955
14
SFAS 158 Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans
114,353,132
93,986,124
145,643,703
62,695,553
15
VA Demand Response Program - Rate Order: VA SCC PUE-2011-0001
4,050,459
1,012,687
981,014
4,082,132
16
Dresden Operating Costs - VA - Rate Order: VA SCC PUE-2011-00036
3,090,646
2,670,301
2,424,452
3,336,495
17
SFAS 106 Medicare Subsidy - Amortization period - 1/2013 to 12/2024
2,355,273
588,818
1,766,455
18
SFAS 109 Deferred Federal Income Tax
98,076,992
62,555,566
63,982,724
96,649,834
19
SFAS 109 Deferred State Income Tax
258,429,068
52,140,209
79,305,907
231,263,370
20
Carbon Capture and Storage Project FEED Study Costs - Rate Order: WV PSC Case 13-0467-E-GI
260,520
183,897
76,623
21
WV Vegetation Management Program Costs - Rate Order: WV PSC Case 13-0557-E-P - Rate Order: WV PSC Case 14-1152-E-42T
45,368,828
33,459,373
11,909,455
22
NBV ARO's Retired Plants - Rate Order: VA SCC PUE-2014-0026 - Rate Order: WV PSC 14-1151-E-D
29,758,986
350,671
29,408,315
23
M&S Retiring Plants - Rate Order: VA SCC PUE-2014-0026 - Rate Order: WV PSC 14-1151-E-D
435,780
36,324
399,456
24
Unrecovered Fuel - Common Wealth Virginia - Per Agreement with Commonwealth of Virginia. Effective June 4, 2015.
266,029
1,166,691
39,581
1,393,139
25
WV Delayed Base Rate Increase - Case No. 16-0179-E-T-PC - Amortization Period: 7/2016 - 6/2018
570,865
570,865
26
WV Air Quality Permit Fees - Rate Order: WV 15-0722-E-P
390,830
123,420
267,410
27
WV EE/DR - Company Funded - Case No. PUE-2014-00039
4,701,148
84,000
940,216
3,844,932
28
Greenhat Default Contingency
5,366
5,366
29
WV Deferred Rate Case Expenses - WVPSC Case #18-0646-E-42T - Amortization Period: 03/2019 - 02/2022
207,526
79,015
256,894
29,647
30
VA Renewable Energy Portfolio Standard - VA SCC Case No. PUE-2009-00038
6,254,966
22,248,823
28,503,789
31
WV Felman Premium/Discount ENEC
2,585,697
2,585,697
32
COVID-19 Costs - WV General Order: WVPSC 262.4 - VA SCC Case No. PUR-2020-00074
5,238,190
5,422,420
2,629,923
8,030,687
33
Carrying Chgs-COVID-19 Costs - VA SCC Case No. PUR-2020-00074
79,658
427,820
7,413
500,065
34
Equity Carrying Chgs-COVID-19 Costs - VA SCC Case No. PUR-2020-00074
33,641
76
187,258
220,823
35
Glen Lyn Ash Pond ARO - VA HB443
198,802,442
90,729,926
289,532,368
36
Carrying Chgs-VA Broadband Pilot - VA SCC Case No. PUR-2019-00145
10,134
365,711
46,112
329,733
37
Equity Carrying Chgs-VA Broadband Pilot - VA SCC Case No. PUR-2019-00145
4,301
18,620
159,631
145,312
38
VA T-RAC Costs - VA SCC Case No. PUE-2009-00031
18,760,167
36,824,124
18,346,700
37,237,591
39
VA Retired Coal Plants - VA SCC Case No. PUR-2020-00015 - Amortization Period: 01/2020 - 05/2025
39,919,349
9,038,340
30,881,009
40
VA E-RAC CCR Expenses - VA SCC Case No. PUR-2020-00015 - Amortization Period: 10/2021 - 09/2022
9,257,000
8,153,428
4,763,104
12,647,324
41
VA Major Storm Expense - VA SCC Case No. PUR-2020-00015
3,476,775
12,147,916
473,768
15,150,923
42
VA Broadband Under Recovery
59,267
2
59,265
43
LSE Formula Rate Defer-Dep
2,695,884
2,695,884
44
WV Deferred Storm Expense
53,674,877
53,674,877
45
WV MRBC Surcharge Under Recovery
2,581,415
1,749,621
831,794
46
WV CCR/ELG AFUDC Deferral - Amortization Period: 09/2021 - 08/2022
1,107,808
465,343
642,465
47
VA Distribution Substation Depreciation Deferral
297,740
297,740
48
VA Distribution Substation Carrying Charge Deferral
976,499
976,499
49
VA Distribution Substation Equity Carrying Charge Deferral
696,172
696,172
50
VA E-RAC Deferral AFUDC - Amortization Period: 10/2021 - 09/2022
259,696
64,924
194,772
51
VA RGGI Deferral
624,847
283,866
340,981
52
VCEA Virginia RPS Under Recovery
9,258,775
7,108,932
2,149,843
53
VA E-RAC Under Recovery
1,333,385
1,099,703
233,682
54
APCO CRR Under Recovery
453,069
62,636
390,433
55
FERC Formula Rates Under Recovery
3,451,631
3,451,631
56
VA EE-RAC Under Recovery -Case No. PUR - 2017-00126
1,342,842
72,727
1,415,569
57
2020 PJM Transmission True-Up - VA SCC Case No. PUR-2020-00015
11,506,629
505,597
12,012,226
44
TOTAL
883,585,010
734,262,586
488,373,954
1,129,473,642


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: OtherRegulatoryAssetsWrittenOffAccountCharged
234, 242, 456, 447, 229
(b) Concept: OtherRegulatoryAssetsWrittenOffAccountCharged
440, 442, 908
(c) Concept: OtherRegulatoryAssetsWrittenOffAccountCharged
244, 254, 175
(d) Concept: OtherRegulatoryAssetsWrittenOffAccountCharged
228, 165, 242, 129
(e) Concept: OtherRegulatoryAssetsWrittenOffAccountCharged
411, 403, 244
(f) Concept: OtherRegulatoryAssetsWrittenOffAccountCharged
411, 506, 154
(g) Concept: OtherRegulatoryAssetsWrittenOffAccountCharged
440, 442, 908
(h) Concept: OtherRegulatoryAssetsWrittenOffAccountCharged
232, 253, 561, 566
(i) Concept: OtherRegulatoryAssetsWrittenOffAccountCharged
903, 904, 426, 506

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
MISCELLANEOUS DEFFERED DEBITS (Account 186)
  1. Report below the particulars (details) called for concerning miscellaneous deferred debits.
  2. For any deferred debit being amortized, show period of amortization in column (a)
  3. Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
CREDITS
Line No.
Description of Miscellaneous Deferred Debits
(a)
Balance at Beginning of Year
(b)
Debits
(c)
Credits Account Charged
(d)
Credits Amount
(e)
Balance at End of Year
(f)
1
Property Taxes West Virginia
76,829,307
84,151,835
82,438,126
78,543,016
2
Property Taxes Ohio
1,976,830
5,654,266
1,976,830
5,654,266
3
Agency Fees - Factored A/R
2,719,437
27,599,907
27,319,914
2,999,430
4
Labor Accruals - Balance Sheet
665
72,198
71,370
1,493
5
Miscellaneous
61,943
5,423,654
5,160,827
324,770
6
Property Taxes - Capital Leases West Virginia
86,985
778,570
778,570
86,985
7
Unamortized Credit Line Fees Amortization through June 2022
489,209
1,059,457
480,865
1,067,801
8
Def Lease Assets - Non Taxable
148,059
822,323
912,103
58,279
9
Deferred Urea Expense
993,226
25,586,429
23,976,990
2,602,665
10
VA Sales/Use Tax Surcharge
1,018,518
1,557,990
1,638,587
1,099,115
11
Estimated Barging Bills
256,399
67,576,611
66,925,366
907,644
47
Miscellaneous Work in Progress
2,410,889
1,805,188
48
Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49
TOTAL
84,954,431
92,952,422


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged
142, 143, 232, 253, 593, 243, 588
(b) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged
142, 232, 154
(c) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged
151, 154, 232, 234

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes.
  2. At Other (Specify), include deferrals relating to other income and deductions.
Line No.
DescriptionOfAccumulatedDeferredIncomeTax
Description and Location
(a)
AccumulatedDeferredIncomeTaxes
Balance at Beginning of Year
(b)
AccumulatedDeferredIncomeTaxes
Balance at End of Year
(c)
1
Electric
2
Interest Expense Capitalized for Tax
51,506,694
52,039,166
3
CIAC
8,950,591
12,068,245
4
DSIT Normalized
16,391,724
12,165,004
5
Accrued Book Removal Costs
66,976,322
67,676,004
6
Accrued Book ARO Expenses
65,742,850
84,970,740
7
Other
27,368,254
26,378,365
8
TOTAL Electric (Enter Total of lines 2 thru 7)
236,936,435
255,297,524
9
Gas
15
Other
16
TOTAL Gas (Enter Total of lines 10 thru 15)
17.1
Other (Specify)
257,907,218
233,465,850
17
Other (Specify)
18
TOTAL (Acct 190) (Total of lines 8, 16 and 17)
494,843,653
488,763,374
Notes


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
CAPITAL STOCKS (Account 201 and 204)
  1. Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible.
  2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.
  3. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued.
  4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
  5. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year.
  6. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.
Class and Series of Stock and Name of Stock Series
(a)
Number of Shares Authorized by Charter
(b)
Par or Stated Value per Share
(c)
Call Price at End of Year
(d)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares
(e)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount
(f)
Held by Respondent As Reacquired Stock (Acct 217) Shares
(g)
Held by Respondent As Reacquired Stock (Acct 217) Cost
(h)
Held by Respondent In Sinking and Other Funds Shares
(i)
Held by Respondent In Sinking and Other Funds Amount
(j)
1
Common Stock (Account 201)
2
30,000,000
13,499,500
260,457,768
5
Total
30,000,000
13,499,500
260,457,768
6
Preferred Stock (Account 204)
7
8
9
10
Total
1
Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5
Total


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2022-05-19
Year/Period of Report

End of:
2021
/
Q4
Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change.
  1. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation.
  2. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related.
  3. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related.
  4. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.
Item
(a)
Amount
(b)
1
DonationsReceivedFromStockholdersAbstract
Donations Received from Stockholders (Account 208)
2
DonationsReceivedFromStockholders
Beginning Balance Amount
1,825,984,502
3.1
IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders
Increases (Decreases) from Sales of Donations Received from Stockholders
4
DonationsReceivedFromStockholders
Ending Balance Amount
1,825,984,502
5
ReductionInParOrStatedValueOfCapitalStockAbstract
Reduction in Par or Stated Value of Capital Stock (Account 209)
6
ReductionInParOrStatedValueOfCapitalStock
Beginning Balance Amount
433
7.1
IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock
Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8
ReductionInParOrStatedValueOfCapitalStock
Ending Balance Amount
433
9
GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract
Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10
GainOnResaleOrCancellationOfReacquiredCapitalStock
Beginning Balance Amount
11.1
IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock
Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12
GainOnResaleOrCancellationOfReacquiredCapitalStock
Ending Balance Amount
13
MiscellaneousPaidInCapitalAbstract
Miscellaneous Paid-In Capital (Account 211)
14
MiscellaneousPaidInCapital
Beginning Balance Amount
2,642,015
15.1
IncreasesDecreasesDueToMiscellaneousPaidInCapital
Increases (Decreases) Due to Miscellaneous Paid-In Capital
16
MiscellaneousPaidInCapital
Ending Balance Amount
2,642,015
17
OtherPaidInCapitalAbstract
Historical Data - Other Paid in Capital
18
OtherPaidInCapitalDetail
Beginning Balance Amount
19.1
IncreasesDecreasesInOtherPaidInCapital
Increases (Decreases) in Other Paid-In Capital
20
OtherPaidInCapitalDetail
Ending Balance Amount
40
OtherPaidInCapital
Total
1,828,626,950


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
CAPITAL STOCK EXPENSE (Account 214)
  1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
  2. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.
NameOfClassAndSeriesOfStock
Class and Series of Stock
(a)
CapitalStockExpense
Balance at End of Year
(b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
TOTAL


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
LONG-TERM DEBT (Account 221, 222, 223 and 224)
  1. Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt.
  2. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number.
  3. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number.
  4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number.
  5. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates.
  6. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge.
  7. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote.
  8. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies.
  9. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.
ClassAndSeriesOfObligationCouponRateDescription
Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates)
(a)
RelatedAccountNumber
Related Account Number
(b)
Principal Amount of Debt Issued
(c)
LongTermDebtIssuanceExpensePremiumOrDiscount
Total Expense, Premium or Discount
(d)
LongTermDebtIssuanceExpenses
Total Expense
(e)
LongTermDebtPremium
Total Premium
(f)
LongTermDebtDiscount
Total Discount
(g)
NominalDateOfIssue
Nominal Date of Issue
(h)
DateOfMaturity
Date of Maturity
(i)
AmortizationPeriodStartDate
AMORTIZATION PERIOD Date From
(j)
AmortizationPeriodEndDate
AMORTIZATION PERIOD Date To
(k)
Outstanding (Total amount outstanding without reduction for amounts held by respondent)
(l)
Interest for Year Amount
(m)
1
Bonds (Account 221)
2
Appalachian Consumer Rate Relief Funding LLC
3
Tranche A-1, 2.0076%, Due 2024
215,800,000
2,416,193
(a)
9,879
11/15/2013
02/01/2024
11/15/2013
02/01/2023
35,579,231
1,131,296
4
- Expense, Premium (P), Discount (D)
5
Tranche A-2, 3.7722%, Due 2031
164,500,000
1,841,815
(b)
7,530
11/15/2013
08/01/2031
11/15/2013
08/01/2028
164,500,000
5,960,601
6
Subtotal
380,300,000
4,258,008
17,409
200,079,231
7,091,897
7
Reacquired Bonds (Account 222)
8
9
10
11
Subtotal
12
Advances from Associated Companies (Account 223)
13
14
15
16
Subtotal
17
Other Long Term Debt (Account 224)
18
19
20
21
Subtotal
5,151,059,040
47,474,940
22,647,500
4,782,910,721
204,855,741
33 TOTAL
5,531,359,040
4,982,989,952
211,947,638


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: BondsDiscount
Issuance    : Tranche A-1, 2.0076%, Due 2024
Principal Amount    : $215,800,000
Date of Issuance    : 11/15/2013
Date of Maturity    : 02/01/2024
Date of maturity (02/01/2024) is when all required payments must be made.
The amortization period end date being used (02/01/2023) is the scheduled final payment date.
(b) Concept: BondsDiscount
Issuance     : Tranche A-2, 3.7722%, Due 2031
Principal Amount     : $164,500,000
Date of Issuance     : 11/15/2013
Date of Maturity     : 08/01/2031
Date of maturity (08/01/2031) is when all required payments must be made.
The amortization period end date being used (08/01/2028) is the scheduled final payment date.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
  1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount.
  2. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members.
  3. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.
Particulars (Details)
(a)
Amount
(b)
1
Net Income for the Year (Page 117)
348,937,055
2
Reconciling Items for the Year
3
4
Taxable Income Not Reported on Books
5
6
7
8
9
Deductions Recorded on Books Not Deducted for Return
10
11
12
13
14
Income Recorded on Books Not Included in Return
15
16
17
18
19
Deductions on Return Not Charged Against Book Income
20
21
22
23
24
25
26
27
Federal Tax Net Income
36,688,668
28
Show Computation of Tax:
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
  1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts.
  2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes.
  3. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts.
  4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
  5. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d).
  6. Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses.
  7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority.
  8. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts.
  9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
BALANCE AT BEGINNING OF YEAR BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED
Line No.
DescriptionOfTaxesAccruedPrepaidAndCharged
Kind of Tax (See Instruction 5)
(a)
TypeOfTax
Type of Tax
(b)
TaxJurisdiction
State
(c)
TaxYear
Tax Year
(d)
TaxesAccrued
Taxes Accrued (Account 236)
(e)
PrepaidTaxes
Prepaid Taxes (Include in Account 165)
(f)
TaxesCharged
Taxes Charged During Year
(g)
TaxesPaid
Taxes Paid During Year
(h)
TaxAdjustments
Adjustments
(i)
TaxesAccrued
Taxes Accrued (Account 236)
(j)
PrepaidTaxes
Prepaid Taxes (Included in Account 165)
(k)
TaxesAccruedPrepaidAndCharged
Electric (Account 408.1, 409.1)
(l)
IncomeTaxesExtraordinaryItems
Extraordinary Items (Account 409.3)
(m)
AdjustmentsToRetainedEarnings
Adjustment to Ret. Earnings (Account 439)
(n)
TaxesIncurredOther
Other
(o)
1
Federal Tax
10,400,223
0
4,943,740
32,552,283
38,008,766
0
9,367,566
4,423,826
2
Subtotal Federal Tax
10,400,223
0
4,943,740
32,552,283
38,008,766
0
9,367,566
4,423,826
3
Local Tax
2019
8,906
0
8,906
0
4
Local Tax
WV
2020
3,022,409
0
5,361
3,017,048
0
0
5,361
5
Local Tax
WV
2021
0
0
14,433,290
11,076,357
3,356,933
0
14,369,302
63,988
6
Subtotal Local Tax
3,031,315
0
14,427,929
14,093,405
3,365,839
0
14,369,302
58,627
7
Other Taxes
TN
2020
8
Other Taxes
TN
2021
9
Other Taxes
WV
2020
731,496
0
731,496
0
0
10
Other Taxes
WV
2021
0
0
1,463,000
1,463,000
0
1,463,000
11
Subtotal Other Tax
731,496
0
1,463,000
731,496
1,463,000
0
1,463,000
12
Property Tax
AR
2020
0
0
3,078
3,078
0
0
3,078
13
Property Tax
CO
2020
0
0
4,861
4,861
0
0
4,861
14
Property Tax
LA
2021
0
0
1,115
1,115
0
0
1,115
15
Property Tax
MO
2021
0
0
23,000
14,531
8,469
0
23,000
16
Property Tax
NE
2019
0
0
360
360
0
0
360
17
Property Tax
OH
2019
2,473,075
0
556,847
1,916,228
0
0
556,846
1
18
Property Tax
OH
2020
1,976,830
0
9
9
1,976,830
0
1,976,839
1,976,830
19
Property Tax
OH
2021
0
0
5,654,266
5,654,266
0
5,654,266
20
Property Tax
TN
2020
1,407,500
0
14,821
1,392,679
0
0
14,778
43
21
Property Tax
TN
2021
0
0
1,475,900
1,475,900
0
1,467,974
7,926
22
Property Tax
VA
2019
0
0
943
943
0
0
943
23
Property Tax
VA
2020
454,727
0
348,863
803,447
143
0
348,540
323
24
Property Tax
VA
2021
0
0
27,484,204
25,977,518
1,506,686
0
26,731,087
753,117
25
Property Tax
WV
2019
26,135,030
0
2,320
26,137,350
0
0
25,425,095
25,422,775
26
Property Tax
WV
2020
52,434,205
0
454,934
26,656,291
26,232,848
0
25,708,038
25,253,104
27
Property Tax
WV
2021
0
0
53,818,021
82
53,817,939
0
97,717
53,720,304
28
Property Tax
WY
2020
0
0
3,600
2,312
1,288
0
3,600
29
Property Tax
AL
2021
0
0
6
6
0
0
6
30
Subtotal Property Tax
84,881,367
0
88,703,812
82,910,810
90,674,369
0
81,184,609
7,519,203
31
UNEMPLOYMENT 2021
Unemployment Tax
13,695
0
80,710
76,346
18,059
0
47,778
32,932
32
STATE UNEMPLOYMENT 2021
Unemployment Tax
KY
296
0
317
317
296
0
3
320
33
STATE UNEMPLOYMENT 2021
Unemployment Tax
OH
337
0
3,579
3,204
712
0
2,324
1,255
34
STATE UNEMPLOYMENT 2021
Unemployment Tax
TN
1
0
4
2
3
0
4
35
STATE UNEMPLOYMENT 2021
Unemployment Tax
VA
8,627
0
47,531
45,848
10,310
0
29,575
17,956
36
STATE UNEMPLOYMENT 2021
Unemployment Tax
WV
21,651
0
201,276
194,703
28,224
0
124,223
77,053
37
Subtotal Unemployment Tax
44,607
0
333,417
320,420
57,604
0
203,897
129,520
38
Sales And Use Tax
OH
2020
26,156
15,000
8,889
2,267
0
0
1
8,888
39
Sales And Use Tax
OH
2021
0
0
181,533
115,350
79,133
12,950
715
182,248
40
Sales And Use Tax
TN
2019
0
0
112
112
0
0
97
15
41
Sales And Use Tax
TN
2020
6,375
100
100
6,375
0
0
100
42
Sales And Use Tax
TN
2021
0
0
2,191
1,483
708
0
1
2,190
43
Sales And Use Tax
VA
2020
180,102
0
62,349
242,451
0
0
62,349
44
Sales And Use Tax
VA
2021
0
0
2,945,721
2,637,029
308,692
0
113
2,945,834
45
Sales And Use Tax
WV
2020
255,954
1,371,756
1,777,633
661,831
0
0
1,777,633
46
Sales And Use Tax
WV
2021
0
0
3,703,012
5,210,147
348,533
1,855,668
816
3,702,196
47
Subtotal Sales And Use Tax
468,587
1,386,856
8,663,762
8,877,045
737,066
1,868,618
85
8,663,677
48
Income Tax
IL
2017
163,298
0
163,298
0
49
Income Tax
IL
2018
149,310
0
1
149,311
0
1
50
Income Tax
IL
2019
324,392
0
324,392
0
51
Income Tax
IL
2020
122,797
0
18,434
141,231
0
18,434
52
Income Tax
IL
2021
0
0
20,094
20,094
0
20,093
1
53
Income Tax
KY
2020
10,553
0
12,914
2,361
0
12,914
54
Income Tax
KY
2021
0
0
9,540
9,540
0
9,540
55
Income Tax
MI
2017
6,145
0
6,145
0
56
Income Tax
MI
2018
6,918
0
6,918
0
57
Income Tax
MI
2019
3,226
0
3,226
0
58
Income Tax
MI
2020
2,414
0
2,414
0
59
Income Tax
MI
2021
0
1,351
1,351
0
1,351
60
Income Tax
MULTI
2019
8,915
0
8,915
0
61
Income Tax
NOL
2011
0
0
0
62
Income Tax
TN
2002
0
0
0
63
Income Tax
TN
2016
4,104
0
4,104
0
64
Income Tax
TN
2017
501,938
0
501,938
0
65
Income Tax
TN
2018
432,375
0
16,345
416,030
0
66
Income Tax
TN
2019
204,591
0
204,591
0
67
Income Tax
TN
2020
467,901
0
16,583
20,300
504,784
0
16,583
68
Income Tax
TN
2021
0
0
56,581
147,400
90,819
0
56,581
69
Income Tax
VA
2020
0
0
8
8
0
8
70
Income Tax
VA
2021
0
0
8
8
0
8
71
Income Tax
WV
2002
0
0
0
0
72
Income Tax
WV
2017
1,489,463
0
1,489,463
0
73
Income Tax
WV
2018
767,996
0
767,996
0
74
Income Tax
WV
2019
17,011,204
0
17,011,204
0
75
Income Tax
WV
2020
447,758
0
382,402
830,160
0
382,402
76
Income Tax
WV
2021
0
0
2,504,514
2,504,514
0
2,504,514
77
Subtotal Income Tax
13,750,658
0
2,161,748
184,045
15,728,361
0
2,592,071
430,323
78
Excise Tax
2021
0
0
16,433
16,433
0
0
16,433
79
0
0
0
0
80
Subtotal Excise Tax
0
0
16,433
16,433
0
0
16,433
81
Franchise Tax
KY
2019
1,637
0
1,637
0
82
Franchise Tax
KY
2020
1,637
0
1,637
0
83
Franchise Tax
NC
2017
4,035
0
46
3,989
0
46
84
Franchise Tax
NC
2018
200
0
200
0
85
Franchise Tax
NC
2019
1,910
0
1,910
0
86
Franchise Tax
NC
2020
1,910
0
1,910
0
87
Franchise Tax
NC
2021
0
0
203
2,100
2,303
0
203
88
Franchise Tax
TN
2002
0
0
1,707
1,707
0
1,707
89
Franchise Tax
TN
2017
88,451
0
88,451
0
90
Franchise Tax
TN
2018
9,373
0
9,373
0
91
Franchise Tax
TN
2019
196,218
0
196,218
0
92
Franchise Tax
TN
2020
262,218
0
262,218
0
93
Franchise Tax
TN
2021
0
0
21,037
21,037
0
21,037
94
Franchise Tax
WV
2002
0
0
241,181
241,181
0
241,181
95
Subtotal Franchise Tax
559,519
0
221,694
2,100
779,113
0
221,694
96
Other State Tax
KY
2019
0
0
2,397
2,397
0
0
2,397
97
Other State Tax
OH
2020
24,900
0
24,580
320
0
0
24,580
98
Other State Tax
OH
2021
0
0
40,087
16,687
23,400
0
40,087
99
Other State Tax
VA
2017
0
0
218,918
218,918
100
Other State Tax
VA
2018
68,884
0
68,884
0
101
Other State Tax
VA
2019
2,350,989
0
1,625,253
1,625,277
2,350,965
0
1,625,253
102
Other State Tax
VA
2020
794,558
0
186,736
952,200
344,378
0
186,736
103
Other State Tax
VA
2021
0
0
9,185,822
6,421,600
2,764,222
0
9,185,822
104
Other State Tax
WV
2020
1,728,506
0
162,937
1,565,569
0
0
162,937
105
Other State Tax
WV
2021
0
0
34,762,184
32,682,591
2,079,593
0
38,031,196
3,269,012
106
Other State Tax
FIN48
0
0
0
0
107
Subtotal Other State Tax
128,091
0
41,986,190
40,011,293
2,102,988
0
45,038,681
3,052,491
108
Other License And Fees Tax
WV
2019
72
0
72
0
109
Other License And Fees Tax
WV
2020
240
0
240
0
110
Other License And Fees Tax
WV
2021
0
0
240
240
0
111
Subtotal Other License And Fees Tax
312
0
240
552
0
112
FICA 2021
Federal Insurance Tax
1,837,495
0
13,112,107
15,810,857
2,468,695
1,607,440
0
7,704,154
5,407,953
113
2360104 FICA
Federal Insurance Tax
2,832,986
0
2,832,986
0
0
114
2360105 FICA CARES ACT
Federal Insurance Tax
2,832,986
0
364,302
3,197,288
0
115
Subtotal Payroll Tax
7,503,467
0
13,112,107
15,810,857
11
4,804,728
0
7,704,154
5,407,953
40
TOTAL
100,698,572
1,386,856
176,033,832
195,510,427
11
81,703,750
1,868,618
160,698,492
15,335,340


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)

Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.

Deferred for Year Allocations to Current Year's Income
Line No.
Account Subdivisions
(a)
Balance at Beginning of Year
(b)
Account No.
(c)
Amount
(d)
Account No.
(e)
Amount
(f)
Adjustments
(g)
Balance at End of Year
(h)
Average Period of Allocation to Income
(i)
ADJUSTMENT EXPLANATION
(j)
1
Electric Utility
2
3%
3
4%
4
7%
5
10%
318,791
11,857
306,934
32 Years
6
State DITC
7
30
8
TOTAL Electric (Enter Total of lines 2 thru 7)
318,791
11,857
306,934
9
Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10
`
47 OTHER TOTAL
48 GRAND TOTAL
318,791
306,934


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
OTHER DEFERRED CREDITS (Account 253)
  1. Report below the particulars (details) called for concerning other deferred credits.
  2. For any deferred credit being amortized, show the period of amortization.
  3. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
DEBITS
Line No.
Description and Other Deferred Credits
(a)
Balance at Beginning of Year
(b)
Contra Account
(c)
Amount
(d)
Credits
(e)
Balance at End of Year
(f)
1
T.V. Pole Attachments
1,874,237
6,430,442
6,348,784
1,792,579
2
Deferred Gain - Fiber Optic Leases
3
Amortize through June 2026
3,386,766
891,628
2,495,138
4
Deferred Revenue - Fiber Optic
5
Lines Sold
191,821
108,924
82,897
6
Amortize IRU through May 2021
7
Amortize KDL through Jan 2025
8
Rents Billed in Advance
368,301
184,150
184,151
9
Customer Advance Receipts
17,275,460
17,275,460
16,757,690
16,757,690
10
IPP - System Upgrade Credits
3,332,729
3,226,372
38,895
145,252
11
Federal Mitigation Deferral - NSR
2,229,306
600,000
1,629,306
12
Other Deferred Credits
1,187,834
26,599,694
26,649,396
1,237,536
13
Def Equity Income-Securitization
2,535,932
301,831
2,234,101
14
Reliability First FAC-003
1,069,481
431,712
637,769
15
Assessment
16
Contr In Aid of Constr Advance
635,839
635,839
5,504,231
5,504,231
17
Associated Business Development
227,650
227,650
47
TOTAL
34,315,356
56,913,702
55,298,996
32,700,650


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: DecreaseInOtherDeferredCreditsContraAccount
232, 234, 561, 566, 565, 131, 143, 411, 186, 509, 142

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report


End of:
2021
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1
Accelerated Amortization (Account 281)
2
Electric
3
Defense Facilities
4
Pollution Control Facilities
247,937,383
24,825
12,021,571
235,940,637
5
Other
5.1
Other (provide details in footnote):
8
TOTAL Electric (Enter Total of lines 3 thru 7)
247,937,383
24,825
12,021,571
235,940,637
9
Gas
10
Defense Facilities
11
Pollution Control Facilities
12
Other
12.1
Other (provide details in footnote):
15
TOTAL Gas (Enter Total of lines 10 thru 14)
16
Other
16.1
Other - SFAS 109
(a)
95,799,954
254
24,825
254
3,607,778
92,217,001
17
TOTAL (Acct 281) (Total of 8, 15 and 16)
152,137,429
24,825
12,021,571
24,825
3,607,778
143,723,636
18
Classification of TOTAL
19
Federal Income Tax
152,137,429
24,825
12,021,571
24,825
3,607,778
143,723,636
20
State Income Tax
21
Local Income Tax


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report


End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Description
Year
Balance at Beginning Amounts Debited Amounts Credits Debit Credit Balance End of
Page 272-273 to Acc 410.2 to Acc 411.2 Adjust Adjust
SFAS 109
(95,799,954)
(95,799,954) 24,825  3,607,778  (92,217,001)
Total line 16
(95,799,954)
(95,799,954) 24,825  3,607,778  (92,217,001)

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 282
2
Electric
2,046,396,336
184,686,342
187,815,038
2,043,267,640
3
Gas
4
Other (Specify)
5
Total (Total of lines 2 thru 4)
2,046,396,336
184,686,342
187,815,038
2,043,267,640
6
(a)
Others
639,432,019
40,282,361
144,195,990
535,518,390
9
TOTAL Account 282 (Total of Lines 5 thru 8)
1,406,964,317
184,686,342
187,815,038
40,282,361
144,195,990
1,507,749,250
10
Classification of TOTAL
11
Federal Income Tax
1,406,964,317
184,686,342
187,815,038
40,282,361
144,195,990
1,507,749,250
12
State Income Tax
13
Local Income Tax


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfNonUtilityAccountDetails
Line 6 Footnote
Beg Bal Debits Credits End Bal
SFAS 109 (639,432,019) 40,282,361  144,195,990  (535,518,390)
Total Other - Line 6 (639,432,019) 40,282,361  144,195,990  (535,518,390)

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
  1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other.
  4. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 283
2
Electric
3
Extra. Loss on Retired Plants
17,320,671
17,956
731,323
16,607,304
4
CAPITALIZED SOFTWARE COST?BOOK
25,967,911
4,320,040
301,123
29,986,828
5
DSIT ENTRY - NORMALIZED
90,051,825
91,863
6,186,444
83,957,244
6
Deferred Fuel Costs
46,312,110
45,072,578
9,771,927
81,612,761
7
Book Pension Expense
27,314,948
25,280
1,791,289
25,548,939
8
Other
36,922,058
169,088,122
148,945,865
3
16,779,798
9 TOTAL Electric (Total of lines 3 thru 8)
170,045,407
218,615,839
167,727,971
3
220,933,278
10
Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 TOTAL Other
(a)
520,343,427
335,093
178,358,335
83,977,136
426,297,321
19 TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)
690,388,834
218,615,839
167,727,971
335,093
178,358,335
83,977,139
647,230,599
20
Classification of TOTAL
21
Federal Income Tax
353,903,938
193,480,669
143,388,474
335,093
78,129,519
31,836,930
358,038,637
22
State Income Tax
336,484,896
25,135,170
24,339,497
100,228,816
52,140,209
289,191,962
23
Local Income Tax
NOTES


FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOther
Line 18 Footnote
Beg Bal Dr 410.1 Cr 411.1 Dr 410.2 Cr 411.2 Debits Credits End Bal
SFAS 133 1,187,087  2,572  1,450,448  2,634,963 
Non-Utility 144,225  335,093  479,318 
SFAS 109 519,012,115  178,355,763  82,526,688  423,183,040 
Total 520,343,427  335,093  178,358,335  83,977,136  426,297,321 

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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
Unrealized Gain On Forward Commitments
260,888
16,801,762
40,869,986
24,329,112
2
Netting of Trading Activities related to Unrealized Gains/Losses on Forward Commitments between Regulated Assets/Liabilities
5,235,279
15,628,050
14,230,672
3,837,901
3
FAS 109 Deferred Federal Income Tax
829,167,553
172,369,434
86,824,650
743,622,769
4
FAS 109 Deferred State Income Tax
4,553,899
26,223,388
21,669,489
5
PJM trans enhancement settlement for refund
16,265,598
3,269,956
12,995,642
6
VA EE-RAC Over Recovery -Case No. PUR - 2017-00126
6,378,319
9,635,473
9,283,353
6,026,199
7
APCO Consumer Rate Relief Over Recovery -Rate Order: WV Public Service Commission -Case No. 12-1188-E-PC
516,739
1,633,075
1,116,336
8
WV Broadband Over Recovery
446,477
446,477
9
WV ECS Over Recovery
174,848
174,848
10
VA RPS-RAC Over-Recovery
8,376,192
8,376,192
11
Felman Prem/Discount ENEC-WV
18,284,805
18,284,805
41 TOTAL
857,824,376
242,176,454
205,830,707
821,478,629


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: OtherRegulatoryLiabilitiesDescriptionOfCreditedAccountNumberForDebitAdjustment
175, 182, 244, 456
(b) Concept: OtherRegulatoryLiabilitiesDescriptionOfCreditedAccountNumberForDebitAdjustment
190, 282, 283
(c) Concept: OtherRegulatoryLiabilitiesDescriptionOfCreditedAccountNumberForDebitAdjustment
190, 282, 283

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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
1,378,288,171
1,273,007,898
11,206,650
10,915,394
813,862
810,840
3
CommercialAndIndustrialSalesAbstract
(442) Commercial and Industrial Sales
4
CommercialSalesAbstract
Small (or Comm.) (See Instr. 4)
555,785,591
526,854,763
5,949,362
5,886,796
138,485
137,143
5
IndustrialSalesAbstract
Large (or Ind.) (See Instr. 4)
584,309,527
563,789,888
8,879,317
8,873,358
4,184
4,210
6
PublicStreetAndHighwayLightingAbstract
(444) Public Street and Highway Lighting
7,993,467
7,783,854
64,162
64,508
1,684
1,716
7
OtherSalesToPublicAuthoritiesAbstract
(445) Other Sales to Public Authorities
62,743,388
61,094,193
745,795
729,260
6,227
6,253
8
SalesToRailroadsAndRailwaysAbstract
(446) Sales to Railroads and Railways
9
InterdepartmentalSalesAbstract
(448) Interdepartmental Sales
10
SalesToUltimateConsumersAbstract
TOTAL Sales to Ultimate Consumers
(a)
2,589,120,143
2,432,530,596
26,845,286
26,469,315
964,442
960,162
11
SalesForResaleAbstract
(447) Sales for Resale
341,751,443
253,242,272
6,967,140
5,600,008
15
27
12
SalesOfElectricityAbstract
TOTAL Sales of Electricity
2,930,871,586
2,685,772,868
33,812,426
32,069,323
964,457
960,189
13
ProvisionForRateRefundsAbstract
(Less) (449.1) Provision for Rate Refunds
4,670,543
14
RevenuesNetOfProvisionForRefundsAbstract
TOTAL Revenues Before Prov. for Refunds
2,930,871,586
2,681,102,325
33,812,426
32,069,323
964,457
960,189
15
OtherOperatingRevenuesAbstract
Other Operating Revenues
16
ForfeitedDiscounts
(450) Forfeited Discounts
6,272,184
4,470,847
17
MiscellaneousServiceRevenues
(451) Miscellaneous Service Revenues
(b)
2,206,090
1,896,615
18
SalesOfWaterAndWaterPower
(453) Sales of Water and Water Power
19
RentFromElectricProperty
(454) Rent from Electric Property
21,832,186
24,503,541
20
InterdepartmentalRents
(455) Interdepartmental Rents
21
OtherElectricRevenue
(456) Other Electric Revenues
(c)
41,801,314
21,427,718
22
RevenuesFromTransmissionOfElectricityOfOthers
(456.1) Revenues from Transmission of Electricity of Others
138,990,094
123,846,235
23
RegionalTransmissionServiceRevenues
(457.1) Regional Control Service Revenues
24
MiscellaneousRevenue
(457.2) Miscellaneous Revenues
25
OtherMiscellaneousOperatingRevenues
Other Miscellaneous Operating Revenues
26
OtherOperatingRevenues
TOTAL Other Operating Revenues
211,101,867
176,144,956
27
ElectricOperatingRevenues
TOTAL Electric Operating Revenues
3,141,973,453
2,857,247,281
Line12, column (b) includes $
18,781,557
of unbilled revenues.
Line12, column (d) includes
333,072
MWH relating to unbilled revenues


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: SalesToUltimateConsumers
Detail of Unmetered Sales included in Total Sales to Ultimate Customers:
Account Revenues MWH Sold Average No. of
Customers
440 Residential 10,670,996  67,736  84,333 
442 Commercial 8,232,985  66,987  23,622 
442 Industrial 720,845  6,654  910 
444 Street Lighting 24,167  197  50 
445 Other Public Sales 367,950  3,025  706 
20,016,943  144,599  109,621 
Total Sales to Ultimate Consumers include $1,565,938 of Operating Revenues for distribution service provided to Open Access Customers. Megawatt hours delivered to Open Access Consumers were 342,677 and are included in the reported megawatt hours sold on Pg. 301(d).
(b) Concept: MiscellaneousServiceRevenues
Customer service revenue, including connects, reconnects, disconnects, temporary services and other charges billed to customer.
(c) Concept: OtherElectricRevenue
Descrption YTD 2021 YTD 2020
Assoc. Business Development 9,046,571  7,924,270 
Sale of Renewable Energy Credits 32,293,619  13,061,259 
Amort. Of Deferred Equity 301,831  295,863 
All Other (under $250K each) 159,293  146,326 
Total 41,801,314   21,427,718  

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
GS - General Sales
4
605
0.1513
2
OL-Outdoor Lighting
67,736
10,671,074
0.1575
3
RS - Residential Service
11,208,849
1,367,115,931
809,497
13,847
0.1220
4
RSE - Residential Emp.
69,062
8,449,713
4,124
16,745
0.1223
5
RS-EV RESIDENTIAL SERVICE PLUG IN ELECTRIC VEHICLE CHARGING
142
3,950
33
4,309
0.0278
6
RS-LM-TOD Res. Load MGMT
332
39,694
16
20,627
0.1196
7
RS-TOD-Residential TOD
3,170
332,371
192
16,509
0.1048
8
SGS-Small Gen. Service
10
1,082
31,394
0.1082
9
PA - PUBLIC AUTHORITY
50
5.0060
10
Misc Adjustments
335,362
41 TOTAL Billed Residential Sales
11,349,305
1,386,271,208
813,862
13,945
0.1221
42 TOTAL Unbilled Rev. (See Instr. 6)
142,655
7,983,037
0.0560
43 TOTAL
11,206,650
1,378,288,171
813,862
13,770
0.1230


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
Estimated
4,207
272,902
0.0649
2
SGS-Small General Service
3,617,045
329,612,491
20,320
178,004
0.0911
3
SGS-PA - Small General Service-PA
408
42,354
4
102,000
0.1038
4
SGS-TOD-Small General Service
48,906
4,412,052
675
72,453
0.0902
5
IP-Industrial Power Service
6,995
449,248
1
6,995,000
0.0642
6
LCP-Large Capacity Power
501,565
38,616,257
49
10,236,020
0.0770
7
LGS-TOD - Large General Service-T
25,728
2,219,462
79
325,671
0.0863
8
LPS-Large Power Service
303,791
17,765,347
22
13,808,682
0.0585
9
LPS-TOD-Large Power Ser TOD
28,276
2,115,617
4
7,069,000
0.0748
10
MGS-Medium General Service
239,422
25,027,641
2,830
84,601
0.1045
11
OL-Outdoor Lighting
67,020
8,235,724
0.1229
12
RS-Residential Service
3
324
0.1080
13
SGS-Small General Service
833,761
92,066,504
109,000
7,649
0.1104
14
SGS-TOD-Small General Service
3,160
376,565
547
5,777
0.1192
15
SS-School Service
255,785
27,539,373
1,060
241,307
0.1077
16
SWS-Sanctuary Worship
99,757
12,381,665
3,893
25,625
0.1241
17
Winterplace
1,178
199,335
1
1,178,000
0.1692
18
Misc Adjustments
101,132
41 TOTAL Billed Small or Commercial
6,028,593
560,685,925
138,485
43,532
0.0930
42 TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)
79,231
4,900,334
0.0618
43 TOTAL Small or Commercial
5,949,362
555,785,591
138,485
42,960
0.0934


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
Armstrong
69,986
3,389,492
1
69,986,000
0.0484
2
Constellium
170,577
9,910,638
1
170,577,000
0.0581
3
Estimated
117,815
6,614,538
0.0561
4
Felman
255,025
17,936,821
1
255,025,000
0.0703
5
GS-General Service
883,656
76,081,721
1,384
638,480
0.0861
6
GS-TOD-General Service TOD
1,975
197,618
21
94,048
0.1001
7
IP-Industrial Power Service
310,406
19,007,368
3
103,468,667
0.0612
8
LCP-Large Capacity Power
2,194,189
163,711,254
95
23,096,726
0.0746
9
LGS-TOD - Large General Service-T
529
69,945
3
176,333
0.1322
10
LPS-Large Power Service
3,261,288
182,593,792
98
33,278,449
0.0560
11
LPS-TOD-Large Power Ser TOD
1,031,038
63,061,879
33
31,243,576
0.0612
12
MGS-Medium General Service
136,850
14,619,375
399
342,982
0.1068
13
OL-Outdoor Lighting
6,654
720,845
0.1083
14
SGS-Small General Service
22,047
2,345,131
2,143
10,288
0.1064
15
WV Manufacturing
506,155
27,327,126
1
506,155,000
0.0540
16
WV Recycle
10,138
1,652,975
1
10,138,000
0.1630
17
Misc Adjustments
279,130
41 TOTAL Billed Large (or Ind.) Sales
8,978,328
589,519,648
4,184
2,145,872
0.0657
42 TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)
99,011
5,210,121
0.0526
43 TOTAL Large (or Ind.)
8,879,317
584,309,527
4,184
2,122,208
0.0658


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
Misc Adjustments
41 TOTAL Billed Commercial and Industrial Sales
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
Commonwealth of VA
3,781
386,932
538
7,028
0.1023
2
Estimated
3
GS-General Service
1,442
159,667
25
57,680
0.1107
4
GS-TOD-General Service TOD
646
49,243
5
129,200
0.0762
5
MGS-PA-Med Gen Ser - PA
543
48,873
1
543,000
0.0900
6
OL-Outdoor Lighting
197
24,167
0.1227
7
SGS-Small General Service
2,579
345,788
593
4,349
0.1341
8
SGS-PA -Small Gen Ser - PA
952
120,991
329
2,894
0.1271
9
SL-Street Lighting
54,207
6,883,196
193
280,865
0.1270
10
Misc Adjustments
10,959
41 TOTAL Billed Public Street and Highway Lighting
64,347
8,007,898
1,684
38,211
0.1244
42 TOTAL Unbilled Rev. (See Instr. 6)
185
14,431
43 TOTAL
64,162
7,993,467
1,684
38,101
0.1246


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
Commonwealth of VA
128,993
10,673,717
909
141,906
0.0827
2
Estimated
101
7,905
0.0783
3
Flood Walls
211
14,832
22
9,591
0.0703
4
GS-General Service
23,789
1,679,698
17
1,399,353
0.0706
5
GS-PA -General Service -PA
359,242
28,540,986
642
559,567
0.0794
6
GS-TOD-PA-Gen Ser TOD -PA
2,542
231,056
92
27,630
0.0909
7
LPS-TOD - LARGE POWER SERVICE TOD
1,709
153,131
0.0896
8
LPS-TOD-PA Large Pow Ser
37,541
2,483,758
5
7,508,200
0.0662
9
MGS - MEDIUM GENERAL SERVICE
1,201
120,070
8
150,125
0.1000
10
MGS-PA-Med Gen Ser - PA
151,557
14,712,784
635
238,672
0.0971
11
OL-Outdoor Lighting
3,025
367,950
0.1216
12
Public Authority-Large General Svc-TOD-Pri
100
9,321
1
100,000
0.0932
13
Public Authority-Large General Svc-TOD-Sec
1,691
179,527
19
89,000
0.1062
14
SGS-Small General Service
596
60,051
40
14,900
0.1008
15
SGS-PA- Small Gen Ser - PA
45,689
4,492,767
3,837
11,907
0.0983
16
Misc Adjustments
294,720
41 TOTAL Billed Other Sales to Public Authorities
757,785
63,417,023
6,227
121,693
0.0837
42 TOTAL Unbilled Rev. (See Instr. 6)
11,990
673,635
43 TOTAL
745,795
62,743,388
6,227
119,768
0.0841


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
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 TOTAL Billed Provision For Rate Refunds
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
41 TOTAL Billed - All Accounts
27,178,358
2,607,901,702
964,442
2,363,254
42 TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
333,072
18,781,557
43 TOTAL - All Accounts
26,845,286
2,589,120,145
964,442
2,363,254


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
SALES FOR RESALE (Account 447)
  1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326).
  2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years.

    SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less.

    LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years.

    OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote.

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

  4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k).
  5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided.
  6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser.
  8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser.
  9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24.
  10. Footnote entries as required and provide explanations following all required data.
ACTUAL DEMAND (MW) REVENUE
Line No.
Name of Company or Public Authority (Footnote Affiliations)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Average Monthly Billing Demand (MW)
(d)
Average Monthly NCP Demand
(e)
Average Monthly CP Demand
(f)
Megawatt Hours Sold
(g)
Demand Charges ($)
(h)
Energy Charges ($)
(i)
Other Charges ($)
(j)
Total ($) (h+i+j)
(k)
1
ALLEGHENY ELECTRIC COOPERATIVE
13,306
549,164
549,164
2
AMEREX POWER, LTD
0
1,417
1,417
3
(a)
B.P. ENERGY COMPANY
34,651
803,134
803,134
4
CITIGROUP ENERGY INC.
0
246,731
246,731
5
CITY OF RADFORD, VA
177,573
5,417,397
7,341,058
12,758,455
6
CITY OF SALEM, VA
363,402
10,442,087
16,180,697
26,622,784
7
CRAIG-BOTETOURT ELECTRIC COOP
52,848
1,951,026
2,313,015
4,264,041
8
DUQUESNE LIGHT COMPANY
13,492
545,487
545,487
9
EVOLUTION MARKETS FUTURES LLC
0
6,745
6,745
10
FIRSTENERGY TRADING SERVICES
75,341
3,039,043
3,039,043
11
ICAP ENERGY LLC
0
2,654
2,654
12
IVG ENERGY, LTD
0
5,202
5,202
13
KINGSPORT
1,675,182
41,992,911
53,416,481
33,177,725
128,587,117
14
OHIO POWER COMPANY (AUCTION)
39
1,090
1,090
15
OLD DOMINION ELECTRIC
151,681
5,542,987
6,868,858
12,411,845
16
PJM INTERCONNECTION
3,994,808
4,073,006
132,684,788
11,029,581
147,787,375
17
PJM INTERCONNECTION
0
21,685,993
21,685,993
18
PPL ELECTRIC UTILITIES CORP
104,750
4,557,682
4,557,682
19
RBC CAPITAL MARKET, LLC
0
1,113
1,113
20
TRIDENT BROKERAGE SERVICES, LLC
0
177
177
21
TULLETT PREBON AMERICAS CORP.
0
215
(e)
215
22
(b)
UNITED LIGHT & POWER COMPANY
52,346
1,818,361
2,505,997
4,324,358
23
VIRGINIA TECH
327,023
9,074,359
12,921,135
21,995,494
24
WELLS FARGO SECURITIES, LLC
0
2,939,111
2,939,111
15
Subtotal - RQ
2,800,056
76,239,128
101,547,241
11,491,732
189,278,101
16
Subtotal-Non-RQ
4,167,084
4,073,006
137,369,665
11,030,671
152,473,342
17 Total
6,967,140
80,312,134
238,916,906
22,522,403
341,751,443


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityReceivingElectricityPurchasedForResale
An affiliated company
(b) Concept: NameOfCompanyOrPublicAuthorityReceivingElectricityPurchasedForResale
An affiliated company
(c) Concept: RateScheduleTariffNumber
FERC Electric Tariff, First Revised Volume No. 5
(d) Concept: RateScheduleTariffNumber
The PUCO (Public Utilities Commission Ohio) ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning June 2015. APCo, KPCo, I&M and WPCo participated in the auction process and were awarded tranches of OPCo's SSO load.
(e) Concept: RevenueFromSalesOfElectricityForResale
Margins for Off System Sales (OSS) reported in APCo’s generation formula rates are included in the total revenue amount. The margins are specifically identified in the ledger as a subset of the accounts that make up these OSS revenues.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
ELECTRIC OPERATION AND MAINTENANCE EXPENSES

If the amount for previous year is not derived from previously reported figures, explain in footnote.

Line No.
Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
1
PowerProductionExpensesAbstract
1. POWER PRODUCTION EXPENSES
2
SteamPowerGenerationAbstract
A. Steam Power Generation
3
SteamPowerGenerationOperationAbstract
Operation
4
OperationSupervisionAndEngineeringSteamPowerGeneration
(500) Operation Supervision and Engineering
19,520,337
19,580,783
5
FuelSteamPowerGeneration
(501) Fuel
(a)
384,765,119
485,092,339
6
SteamExpensesSteamPowerGeneration
(502) Steam Expenses
50,532,264
45,366,636
7
SteamFromOtherSources
(503) Steam from Other Sources
8
SteamTransferredCredit
(Less) (504) Steam Transferred-Cr.
9
ElectricExpensesSteamPowerGeneration
(505) Electric Expenses
203,351
158,435
10
MiscellaneousSteamPowerExpenses
(506) Miscellaneous Steam Power Expenses
19,293,080
24,830,921
11
RentsSteamPowerGeneration
(507) Rents
39,073
33,986
12
Allowances
(509) Allowances
612,073
163,232
13
SteamPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 4 thru 12)
474,965,297
575,226,332
14
SteamPowerGenerationMaintenanceAbstract
Maintenance
15
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
(510) Maintenance Supervision and Engineering
2,363,425
1,492,108
16
MaintenanceOfStructuresSteamPowerGeneration
(511) Maintenance of Structures
4,229,814
5,364,801
17
MaintenanceOfBoilerPlantSteamPowerGeneration
(512) Maintenance of Boiler Plant
47,508,488
48,740,249
18
MaintenanceOfElectricPlantSteamPowerGeneration
(513) Maintenance of Electric Plant
13,342,587
12,987,780
19
MaintenanceOfMiscellaneousSteamPlant
(514) Maintenance of Miscellaneous Steam Plant
11,801,008
13,756,943
20
SteamPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 15 thru 19)
79,245,322
82,341,881
21
PowerProductionExpensesSteamPower
TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
554,210,618
657,568,213
22
NuclearPowerGenerationAbstract
B. Nuclear Power Generation
23
NuclearPowerGenerationOperationAbstract
Operation
24
OperationSupervisionAndEngineeringNuclearPowerGeneration
(517) Operation Supervision and Engineering
25
NuclearFuelExpense
(518) Fuel
26
CoolantsAndWater
(519) Coolants and Water
27
SteamExpensesNuclearPowerGeneration
(520) Steam Expenses
28
SteamFromOtherSourcesNuclearPowerGeneration
(521) Steam from Other Sources
29
SteamTransferredCreditNuclearPowerGeneration
(Less) (522) Steam Transferred-Cr.
30
ElectricExpensesNuclearPowerGeneration
(523) Electric Expenses
31
MiscellaneousNuclearPowerExpenses
(524) Miscellaneous Nuclear Power Expenses
32
RentsNuclearPowerGeneration
(525) Rents
33
NuclearPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of lines 24 thru 32)
34
NuclearPowerGenerationMaintenanceAbstract
Maintenance
35
MaintenanceSupervisionAndEngineeringNuclearPowerGeneration
(528) Maintenance Supervision and Engineering
36
MaintenanceOfStructuresNuclearPowerGeneration
(529) Maintenance of Structures
37
MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration
(530) Maintenance of Reactor Plant Equipment
38
MaintenanceOfElectricPlantNuclearPowerGeneration
(531) Maintenance of Electric Plant
39
MaintenanceOfMiscellaneousNuclearPlant
(532) Maintenance of Miscellaneous Nuclear Plant
40
NuclearPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 35 thru 39)
41
PowerProductionExpensesNuclearPower
TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42
HydraulicPowerGenerationAbstract
C. Hydraulic Power Generation
43
HydraulicPowerGenerationOperationAbstract
Operation
44
OperationSupervisionAndEngineeringHydraulicPowerGeneration
(535) Operation Supervision and Engineering
1,612,103
1,994,342
45
WaterForPower
(536) Water for Power
24,080
4,328
46
HydraulicExpenses
(537) Hydraulic Expenses
984,313
1,548,939
47
ElectricExpensesHydraulicPowerGeneration
(538) Electric Expenses
397,988
341,514
48
MiscellaneousHydraulicPowerGenerationExpenses
(539) Miscellaneous Hydraulic Power Generation Expenses
3,347,023
3,564,001
49
RentsHydraulicPowerGeneration
(540) Rents
362,506
358,157
50
HydraulicPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 44 thru 49)
6,728,013
7,802,625
51
HydraulicPowerGenerationContinuedAbstract
C. Hydraulic Power Generation (Continued)
52
HydraulicPowerGenerationMaintenanceAbstract
Maintenance
53
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
(541) Mainentance Supervision and Engineering
241,930
132,398
54
MaintenanceOfStructuresHydraulicPowerGeneration
(542) Maintenance of Structures
2,846,737
2,595,229
55
MaintenanceOfReservoirsDamsAndWaterways
(543) Maintenance of Reservoirs, Dams, and Waterways
2,840,543
2,929,688
56
MaintenanceOfElectricPlantHydraulicPowerGeneration
(544) Maintenance of Electric Plant
2,698,931
3,703,409
57
MaintenanceOfMiscellaneousHydraulicPlant
(545) Maintenance of Miscellaneous Hydraulic Plant
131,686
228,146
58
HydraulicPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 53 thru 57)
8,759,827
9,588,870
59
PowerProductionExpensesHydraulicPower
TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
(b)
15,487,840
17,391,495
60
OtherPowerGenerationAbstract
D. Other Power Generation
61
OtherPowerGenerationOperationAbstract
Operation
62
OperationSupervisionAndEngineeringOtherPowerGeneration
(546) Operation Supervision and Engineering
290,411
243,960
63
Fuel
(547) Fuel
18,842,965
2,852,066
64
GenerationExpenses
(548) Generation Expenses
556,276
497,146
64.1
OperationOfEnergyStorageEquipment
(548.1) Operation of Energy Storage Equipment
65
MiscellaneousOtherPowerGenerationExpenses
(549) Miscellaneous Other Power Generation Expenses
229,348
98,398
66
RentsOtherPowerGeneration
(550) Rents
29
67
OtherPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 62 thru 67)
19,919,028
3,691,570
68
OtherPowerGenerationMaintenanceAbstract
Maintenance
69
MaintenanceSupervisionAndEngineeringOtherPowerGeneration
(551) Maintenance Supervision and Engineering
70
MaintenanceOfStructures
(552) Maintenance of Structures
71
MaintenanceOfGeneratingAndElectricPlant
(553) Maintenance of Generating and Electric Plant
237,571
352,118
71.1
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration
(553.1) Maintenance of Energy Storage Equipment
72
MaintenanceOfMiscellaneousOtherPowerGenerationPlant
(554) Maintenance of Miscellaneous Other Power Generation Plant
73
OtherPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 69 thru 72)
237,571
352,118
74
PowerProductionExpensesOtherPower
TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
20,156,599
4,043,688
75
OtherPowerSuplyExpensesAbstract
E. Other Power Supply Expenses
76
PurchasedPower
(555) Purchased Power
579,121,879
377,188,759
76.1
PowerPurchasedForStorageOperations
(555.1) Power Purchased for Storage Operations
0
77
SystemControlAndLoadDispatchingElectric
(556) System Control and Load Dispatching
2,490,558
2,355,977
78
OtherExpensesOtherPowerSupplyExpenses
(557) Other Expenses
6,760,693
5,349,298
79
OtherPowerSupplyExpense
TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)
588,373,130
384,894,034
80
PowerProductionExpenses
TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)
1,178,228,188
1,063,897,430
81
TransmissionExpensesAbstract
2. TRANSMISSION EXPENSES
82
TransmissionExpensesOperationAbstract
Operation
83
OperationSupervisionAndEngineeringElectricTransmissionExpenses
(560) Operation Supervision and Engineering
14,515,410
12,930,558
85
LoadDispatchReliability
(561.1) Load Dispatch-Reliability
86
LoadDispatchMonitorAndOperateTransmissionSystem
(561.2) Load Dispatch-Monitor and Operate Transmission System
2,043,828
2,188,799
87
LoadDispatchTransmissionServiceAndScheduling
(561.3) Load Dispatch-Transmission Service and Scheduling
88
SchedulingSystemControlAndDispatchServices
(561.4) Scheduling, System Control and Dispatch Services
6,341,973
5,987,262
89
ReliabilityPlanningAndStandardsDevelopment
(561.5) Reliability, Planning and Standards Development
782,506
588,212
90
TransmissionServiceStudies
(561.6) Transmission Service Studies
91
GenerationInterconnectionStudies
(561.7) Generation Interconnection Studies
92
ReliabilityPlanningAndStandardsDevelopmentServices
(561.8) Reliability, Planning and Standards Development Services
1,852,032
1,737,955
93
StationExpensesTransmissionExpense
(562) Station Expenses
(c)
1,499,414
1,454,374
93.1
OperationOfEnergyStorageEquipmentTransmissionExpense
(562.1) Operation of Energy Storage Equipment
94
OverheadLineExpense
(563) Overhead Lines Expenses
186,419
174,437
95
UndergroundLineExpensesTransmissionExpense
(564) Underground Lines Expenses
30,398
1,465
96
TransmissionOfElectricityByOthers
(565) Transmission of Electricity by Others
316,382,461
254,463,359
97
MiscellaneousTransmissionExpenses
(566) Miscellaneous Transmission Expenses
14,394,958
40,014,724
98
RentsTransmissionElectricExpense
(567) Rents
61,491
85,275
99
TransmissionOperationExpense
TOTAL Operation (Enter Total of Lines 83 thru 98)
329,300,973
239,596,972
100
TransmissionMaintenanceAbstract
Maintenance
101
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses
(568) Maintenance Supervision and Engineering
171,417
94,722
102
MaintenanceOfStructuresTransmissionExpense
(569) Maintenance of Structures
71,059
89,901
103
MaintenanceOfComputerHardwareTransmission
(569.1) Maintenance of Computer Hardware
(d)
38,506
31,683
104
MaintenanceOfComputerSoftwareTransmission
(569.2) Maintenance of Computer Software
598,061
772,637
105
MaintenanceOfCommunicationEquipmentElectricTransmission
(569.3) Maintenance of Communication Equipment
44,159
44,801
106
MaintenanceOfMiscellaneousRegionalTransmissionPlant
(569.4) Maintenance of Miscellaneous Regional Transmission Plant
107
MaintenanceOfStationEquipmentTransmission
(570) Maintenance of Station Equipment
3,705,459
2,864,569
107.1
MaintenanceOfEnergyStorageEquipmentTransmission
(570.1) Maintenance of Energy Storage Equipment
108
MaintenanceOfOverheadLinesTransmission
(571) Maintenance of Overhead Lines
23,644,071
13,217,088
109
MaintenanceOfUndergroundLinesTransmission
(572) Maintenance of Underground Lines
10,578
5,447
110
MaintenanceOfMiscellaneousTransmissionPlant
(573) Maintenance of Miscellaneous Transmission Plant
145,042
95,731
111
TransmissionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 101 thru 110)
28,428,353
17,216,579
112
TransmissionExpenses
TOTAL Transmission Expenses (Total of Lines 99 and 111)
357,729,327
256,813,551
113
RegionalMarketExpensesAbstract
3. REGIONAL MARKET EXPENSES
114
RegionalMarketExpensesOperationAbstract
Operation
115
OperationSupervision
(575.1) Operation Supervision
116
DayAheadAndRealTimeMarketAdministration
(575.2) Day-Ahead and Real-Time Market Facilitation
117
TransmissionRightsMarketAdministration
(575.3) Transmission Rights Market Facilitation
118
CapacityMarketAdministration
(575.4) Capacity Market Facilitation
119
AncillaryServicesMarketAdministration
(575.5) Ancillary Services Market Facilitation
120
MarketMonitoringAndCompliance
(575.6) Market Monitoring and Compliance
121
MarketFacilitationMonitoringAndComplianceServices
(575.7) Market Facilitation, Monitoring and Compliance Services
6,603,034
5,580,830
122
RentsRegionalMarketExpenses
(575.8) Rents
123
RegionalMarketOperationExpense
Total Operation (Lines 115 thru 122)
6,603,034
5,580,830
124
RegionalMarketExpensesMaintenanceAbstract
Maintenance
125
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses
(576.1) Maintenance of Structures and Improvements
126
MaintenanceOfComputerHardware
(576.2) Maintenance of Computer Hardware
127
MaintenanceOfComputerSoftware
(576.3) Maintenance of Computer Software
128
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses
(576.4) Maintenance of Communication Equipment
129
MaintenanceOfMiscellaneousMarketOperationPlant
(576.5) Maintenance of Miscellaneous Market Operation Plant
130
RegionalMarketMaintenanceExpense
Total Maintenance (Lines 125 thru 129)
131
RegionalMarketExpenses
TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)
6,603,034
5,580,830
132
DistributionExpensesAbstract
4. DISTRIBUTION EXPENSES
133
DistributionExpensesOperationAbstract
Operation
134
OperationSupervisionAndEngineeringDistributionExpense
(580) Operation Supervision and Engineering
5,546,699
4,433,265
135
LoadDispatching
(581) Load Dispatching
7,211
15,388
136
StationExpensesDistribution
(582) Station Expenses
1,368,052
1,206,100
137
OverheadLineExpenses
(583) Overhead Line Expenses
587,051
1,687,661
138
UndergroundLineExpenses
(584) Underground Line Expenses
2,170,984
2,261,467
138.1
OperationOfEnergyStorageEquipmentDistribution
(584.1) Operation of Energy Storage Equipment
139
StreetLightingAndSignalSystemExpenses
(585) Street Lighting and Signal System Expenses
590,853
87,371
140
MeterExpenses
(586) Meter Expenses
1,785,362
594,852
141
CustomerInstallationsExpenses
(587) Customer Installations Expenses
624,927
746,941
142
MiscellaneousDistributionExpenses
(588) Miscellaneous Expenses
10,652,763
19,071,388
143
RentsDistributionExpense
(589) Rents
1,451,899
1,597,629
144
DistributionOperationExpensesElectric
TOTAL Operation (Enter Total of Lines 134 thru 143)
24,785,802
31,702,062
145
DistributionExpensesMaintenanceAbstract
Maintenance
146
MaintenanceSupervisionAndEngineering
(590) Maintenance Supervision and Engineering
181,056
169,496
147
MaintenanceOfStructuresDistributionExpense
(591) Maintenance of Structures
199,244
179,931
148
MaintenanceOfStationEquipment
(592) Maintenance of Station Equipment
(e)
1,369,389
1,312,620
148.1
MaintenanceOfEnergyStorageEquipment
(592.2) Maintenance of Energy Storage Equipment
149
MaintenanceOfOverheadLines
(593) Maintenance of Overhead Lines
126,395,547
96,387,866
150
MaintenanceOfUndergroundLines
(594) Maintenance of Underground Lines
1,277,470
1,227,471
151
MaintenanceOfLineTransformers
(595) Maintenance of Line Transformers
1,892,232
2,242,445
152
MaintenanceOfStreetLightingAndSignalSystems
(596) Maintenance of Street Lighting and Signal Systems
528,276
463,857
153
MaintenanceOfMeters
(597) Maintenance of Meters
380,371
314,981
154
MaintenanceOfMiscellaneousDistributionPlant
(598) Maintenance of Miscellaneous Distribution Plant
4,759,687
4,570,775
155
DistributionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 146 thru 154)
136,983,273
106,869,442
156
DistributionExpenses
TOTAL Distribution Expenses (Total of Lines 144 and 155)
161,769,075
138,571,504
157
CustomerAccountsExpensesAbstract
5. CUSTOMER ACCOUNTS EXPENSES
158
CustomerAccountsExpensesOperationsAbstract
Operation
159
SupervisionCustomerAccountExpenses
(901) Supervision
478,550
428,418
160
MeterReadingExpenses
(902) Meter Reading Expenses
3,934,277
4,109,056
161
CustomerRecordsAndCollectionExpenses
(903) Customer Records and Collection Expenses
24,315,220
22,414,866
162
UncollectibleAccounts
(904) Uncollectible Accounts
5,625,956
4,605,308
163
MiscellaneousCustomerAccountsExpenses
(905) Miscellaneous Customer Accounts Expenses
135,767
156,085
164
CustomerAccountExpenses
TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)
34,489,770
31,713,733
165
CustomerServiceAndInformationalExpensesAbstract
6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166
CustomerServiceAndInformationalExpensesOperationAbstract
Operation
167
SupervisionCustomerServiceAndInformationExpenses
(907) Supervision
653,360
539,955
168
CustomerAssistanceExpenses
(908) Customer Assistance Expenses
15,033,181
15,531,464
169
InformationalAndInstructionalAdvertisingExpenses
(909) Informational and Instructional Expenses
170
MiscellaneousCustomerServiceAndInformationalExpenses
(910) Miscellaneous Customer Service and Informational Expenses
83,279
71,606
171
CustomerServiceAndInformationExpenses
TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)
15,769,820
16,143,025
172
SalesExpenseAbstract
7. SALES EXPENSES
173
SalesExpenseOperationAbstract
Operation
174
SupervisionSalesExpense
(911) Supervision
539
175
DemonstratingAndSellingExpenses
(912) Demonstrating and Selling Expenses
168,708
279,273
176
AdvertisingExpenses
(913) Advertising Expenses
177
MiscellaneousSalesExpenses
(916) Miscellaneous Sales Expenses
178
SalesExpenses
TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
168,708
279,812
179
AdministrativeAndGeneralExpensesAbstract
8. ADMINISTRATIVE AND GENERAL EXPENSES
180
AdministrativeAndGeneralExpensesOperationAbstract
Operation
181
AdministrativeAndGeneralSalaries
(920) Administrative and General Salaries
46,182,639
45,730,119
182
OfficeSuppliesAndExpenses
(921) Office Supplies and Expenses
5,058,941
3,359,025
183
AdministrativeExpensesTransferredCredit
(Less) (922) Administrative Expenses Transferred-Credit
5,484,021
6,760,299
184
OutsideServicesEmployed
(923) Outside Services Employed
13,463,107
8,899,129
185
PropertyInsurance
(924) Property Insurance
(f)
4,446,810
4,902,652
186
InjuriesAndDamages
(925) Injuries and Damages
3,496,246
6,771,456
187
EmployeePensionsAndBenefits
(926) Employee Pensions and Benefits
5,144,960
5,754,311
188
FranchiseRequirements
(927) Franchise Requirements
189
RegulatoryCommissionExpenses
(928) Regulatory Commission Expenses
10,695,109
6,065,976
190
DuplicateChargesCredit
(929) (Less) Duplicate Charges-Cr.
145,001
134,872
191
GeneralAdvertisingExpenses
(930.1) General Advertising Expenses
728,098
340,179
192
MiscellaneousGeneralExpenses
(930.2) Miscellaneous General Expenses
7,759,245
6,591,353
193
RentsAdministrativeAndGeneralExpense
(931) Rents
1,950,065
1,649,801
194
AdministrativeAndGeneralOperationExpense
TOTAL Operation (Enter Total of Lines 181 thru 193)
93,296,199
83,168,830
195
AdministrativeAndGeneralExpensesMaintenanceAbstract
Maintenance
196
MaintenanceOfGeneralPlant
(935) Maintenance of General Plant
11,869,482
10,451,943
197
AdministrativeAndGeneralExpenses
TOTAL Administrative & General Expenses (Total of Lines 194 and 196)
105,165,681
93,620,773
198
OperationsAndMaintenanceExpensesElectric
TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)
1,859,923,604
1,606,620,658


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: FuelSteamPowerGeneration
The portion of account 501 that is excluded from the fuel costs in APCo's generation formula rate is identified by a query of the general ledger.
(b) Concept: PowerProductionExpensesHydraulicPower
ydraulic Power Generation:
Hydraulic Power Generation includes Pumped Storage – See Page 408.
(c) Concept: StationExpensesTransmissionExpense
Generation Step-Up Units’ (GSUs) O&M expenses included in APCo’s generation formula rates are the ratio of GSU balances to all investment for plant accounts 352 & 353 multiplied by the balance in O&M accounts 562, 569, 570.
(d) Concept: MaintenanceOfComputerHardwareTransmission
Allocated maintenance expenses for joint use computer hardware, computer software and communication equipment are determined by using various factors, which include number of remote terminal units, number of radios, number of employees and other factors assigned to each function.
(e) Concept: MaintenanceOfStationEquipment
Account 592.2 contains $0 for maintenance of energy storage equipment.
(f) Concept: PropertyInsurance
The insurance expenses for generation included in APCo’s generation formula rate are identified by a query of the general ledger.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
PURCHASED POWER (Account 555)
  1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges.
  2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years.

    SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less.

    LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years.

    EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges.

    OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment.

    AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided.
  5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  6. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.
  7. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote.
  8. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13.
  9. Footnote entries as required and provide explanations following all required data.
Actual Demand (MW) POWER EXCHANGES COST/SETTLEMENT OF POWER
Line No.
NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
RateScheduleTariffNumber
Ferc Rate Schedule or Tariff Number
(c)
AverageMonthlyBillingDemand
Average Monthly Billing Demand (MW)
(d)
AverageMonthlyNonCoincidentPeakDemand
Average Monthly NCP Demand
(e)
AverageMonthlyCoincidentPeakDemand
Average Monthly CP Demand
(f)
MegawattHoursPurchasedOtherThanStorage
MegaWatt Hours Purchased (Excluding for Energy Storage)
(g)
MegawattHoursPurchasedForEnergyStorage
MegaWatt Hours Purchased for Energy Storage
(h)
EnergyReceivedThroughPowerExchanges
MegaWatt Hours Received
(i)
EnergyDeliveredThroughPowerExchanges
MegaWatt Hours Delivered
(j)
DemandChargesOfPurchasedPower
Demand Charges ($)
(k)
EnergyChargesOfPurchasedPower
Energy Charges ($)
(l)
OtherChargesOfPurchasedPower
Other Charges ($)
(m)
SettlementOfPower
Total (k+l+m) of Settlement ($)
(n)
1
BEECH RIDGE ENERGY LLC
255,460
22,833,465
22,833,465
2
BLUFF POINT WIND ENERGY CENTER
380,595
14,169,269
14,169,269
3
CAMP GROVE WIND FARM LLC
205,754
13,637,744
13,637,744
4
FOWLER RIDGE III WIND FARM LLC
175,796
12,659,106
12,659,106
5
GAULEY RIVER POWERS PARTNERS
139,456
5,483,542
5,483,542
6
GRAND RIDGE ENERGY II LLC
116,267
11,575,519
11,575,519
7
GRAND RIDGE WIND FARM 3
111,364
11,057,100
11,057,100
8
ICE TRADE VAULT LLC
0
9
LUMINAIRE TECHNOLOGIES, INC.
861
2,341
47,991
50,332
10
OLD DOMINION ELECTRIC
3
2,673
2,673
11
OVEC POWER SCHEDULING
1,578,993
61,109,292
43,173,818
104,283,110
12
PJM INTERCONNECTION
8,372,173
186,822
370,889,357
371,076,179
13
(a)
WIND DEFERRAL
0
12,293,840
12,293,840
15 TOTAL
11,336,722
0
0
0
61,298,455
517,823,424
579,121,879


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Deferral to track incremental costs related to approved RPS program, PER Virginia State Corporation Commission in APCo's RPS-RAC Case No. PUE-2020-00015.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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
PJM Network Integ Trans Rev Whlsle
Various
Various
Various
Various
11,884,767
11,884,767
2
PJM Network Integ Trans Serv
Various
Various
Various
Various
50,459,240
50,459,240
3
PJM Trans Enhancement Rev
Various
Various
Various
Various
9,240,755
9,240,755
4
PJM Trans Enhancement Rev Whlsle
Various
Various
Various
Various
284,018
284,018
5
PJM Trans Enhancement Rev - Affil
Various
Various
Various
Various
192,049
192,049
6
PJM Network Integ Rev - Affil
Various
Various
Various
Various
57,921,743
57,921,743
7
PJM Point to Point Trans Serv
Various
Various
Various
Various
6,410,949
6,410,949
8
PJM Trans Owner Admin Revenue
Various
Various
Various
Various
11,284
11,284
9
PJM Trans Owner Serv Rev Whlsle
Various
Various
Various
Various
50,698
50,698
10
PJM Power Factor Credits Rev Whlsl
Various
Various
Various
Various
(b)
97,325
97,325
11
PJM Power Factor Credits Rev Nonaffiliated
Various
Various
Various
Various
(c)
202,870
202,870
12
PJM Trans Distribution & Meter
Various
Various
Various
Various
(d)
106,004
106,004
13
PJM Trans Owner Serv Revenue Affiliated
Various
Various
Various
Various
2,128,392
2,128,392
35 TOTAL
0
0
0
136,393,521
2,190,374
406,199
138,990,094


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: RateScheduleTariffNumber
Effective October 1, 2004, the administration of the transmission tariff was turned over to PJM. PJM does not provide any detail except for the total revenue by the major classes listed. OATT (Open Access Transmission Tariff) 3rd revised Volume No. 6.
(b) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Per Proforma ILDSA (Interconnection and Local Delivery Service Agreement) AEP Tariff 3rd Revised Volume No. 6
(c) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Per Proforma ILDSA (Interconnection and Local Delivery Service Agreement) AEP Tariff 3rd Revised Volume No. 6
(d) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Per Proforma ILDSA (Interconnection and Local Delivery Service Agreement) AEP Tariff 3rd Revised Volume No. 6

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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
PJM-Enhancements
(a)
39,251,568
39,251,568
2
PJM-NITS
(b)
275,566,186
275,566,186
3
PJM - Trans Owner Serv
(c)
1,564,707
1,564,707
TOTAL
0
0
0
0
316,382,461
316,382,461


FOOTNOTE DATA

(a) Concept: OtherChargesTransmissionOfElectricityByOthers
Transmission Enhancement Charges and Credits (PJM OATT Schedule 12)
(b) Concept: OtherChargesTransmissionOfElectricityByOthers
Network Integration Transmission Service Charges - NITS (PJM OATT Attachment H)
(c) Concept: OtherChargesTransmissionOfElectricityByOthers
Transmission Owner Charges and Credits (PJM OATT Tariff Sixth Revised Volume No. 1.)

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.
Description
(a)
Amount
(b)
1
IndustryAssociationDues
Industry Association Dues
498,997
2
NuclearPowerResearchExpenses
Nuclear Power Research Expenses
3
OtherExperimentalAndGeneralResearchExpenses
Other Experimental and General Research Expenses
1,633
4
PublicationAndDistributionExpensesForSecuritiesToStockholders
Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
5
OtherMiscellaneousGeneralExpenses
Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6
Associated Business Development
6,123,111
7
Affiliated Intercompany Billings
699,765
8
Broadband Study
151,344
9
Corporate Contributions and Memberships
99,431
10
Various Chambers of Commerce
17,156
11
Trustee Fees
72,150
12
Utility Corp Borrowing Program Shared Costs
95,530
13
Various Expenses
128
46
MiscellaneousGeneralExpenses
TOTAL
7,759,245


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
  1. Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405).
  2. Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year.
  3. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year.
    Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used.
    In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used.
    For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis.
  4. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
A. Summary of Depreciation and Amortization Charges
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
40,820,370
40,820,370
2
Steam Production Plant
207,937,131
3,337,664
211,274,795
3
Nuclear Production Plant
4
Hydraulic Production Plant-Conventional
6,307,031
30,476
6,337,507
5
Hydraulic Production Plant-Pumped Storage
4,336,435
45,648
4,382,082
6
Other Production Plant
18,020,136
18,020,136
7
Transmission Plant
88,254,494
88,254,494
8
Distribution Plant
162,137,437
69
162,137,505
9
Regional Transmission and Market Operation
10
General Plant
10,628,975
38,391
435,944
11,103,309
11
Common Plant-Electric
12
TOTAL
497,621,638
3,452,247
41,256,314
542,330,199
B. Basis for Amortization Charges
Section A Line 1 Column D represents amortization of capitalized software development costs over a 5 year life and costs associated with the Oracle strategic partnership which are over a 10 year life. Section A Line 10, Column D represents amortization of leasehold improvements over the lives of the related assets.
C. Factors Used in Estimating Depreciation Charges
Line No.
AccountNumberFactorsUsedInEstimatingDepreciationCharges
Account No.
(a)
DepreciablePlantBase
Depreciable Plant Base (in Thousands)
(b)
UtilityPlantEstimatedAverageServiceLife
Estimated Avg. Service Life
(c)
UtilityPlantNetSalvageValuePercentage
Net Salvage (Percent)
(d)
UtilityPlantAppliedDepreciationRate
Applied Depr. Rates (Percent)
(e)
MortalityCurveType
Mortality Curve Type
(f)
UtilityPlantWeightedAverageRemainingLife
Average Remaining Life
(g)
12
13
57,973
61 years
3
3.07
14
117,018
60 years
3
2.97
15
86
0 years
2.02
16
26,929
67 years
4
0.94
17
267
0 years
3.62
18
200,421
60 years
5
2.92
19
1,376,120
61 years
3
3.91
20
20,163
61 years
3
7.26
21
1,570,144
60 years
3
4.06
22
18,634
60 years
3
9.72
23
214,933
67 years
4
5.43
24
50,334
0 years
3.71
25
1,149,600
60 years
5
3.07
26
18,740
8 years
5
10.85
27
126,216
61 years
3
4.96
28
159,493
60 years
3
4.5
29
40,581
67 years
4
2.37
30
127,023
60 years
5
3.1
31
57,653
61 years
3
3.91
32
37,257
60 years
3
2.85
33
10,961
67 years
4
1.31
34
65
0 years
3.76
35
76,277
60 years
5
1.87
36
5,493
61 years
3
5.08
37
29,089
60 years
3
3.2
38
21,795
0 years
2.63
39
6,436
67 years
4
4.26
40
22,949
60 years
5
2.54
41
5,542,650
42
43
570
112 years
24
4.9
44
1,216
112 years
24
9.83
45
3,863
102 years
24
3.08
46
3,839
76 years
24
2.77
47
617
109 years
24
2.69
48
946
109 years
24
2.01
49
678
118 years
24
16.63
50
2,754
106 years
24
2.97
51
7,896
112 years
24
9.32
52
7,441
112 years
24
12.9
53
12,714
102 years
24
2.19
54
12,111
76 years
24
2.19
55
1,696
109 years
24
1.97
56
1,880
109 years
24
2.33
57
6,734
118 years
24
9.35
58
2,767
106 years
24
2.22
59
1,937
112 years
24
6.77
60
3,697
112 years
24
11.69
61
4,184
102 years
24
3.08
62
3,764
76 years
24
2.02
63
8,376
109 years
24
2.99
64
8,696
109 years
24
3.4
65
640
118 years
24
5.23
66
7,717
106 years
24
3.32
67
2,518
112 years
24
7.71
68
1,081
112 years
24
7.18
69
3,103
102 years
24
2.65
70
1,975
76 years
24
4.03
71
1,923
109 years
24
2.16
72
2,191
109 years
24
2.21
73
500
118 years
24
13.51
74
270
106 years
24
3.18
75
942
112 years
24
14.45
76
1,035
112 years
24
9.53
77
3,056
102 years
24
3.27
78
3,123
76 years
24
3.34
79
517
109 years
24
2.66
80
703
109 years
24
2.44
81
307
118 years
24
8.85
82
3,232
106 years
24
2.02
83
3
112 years
24
2.44
84
32
102 years
24
0.98
85
81
76 years
24
0.99
86
49
109 years
24
1.19
87
1
109 years
24
1.16
88
24
106 years
24
2.09
89
133,399
90
91
16,356
75 years
24
2.14
92
32,125
75 years
24
1.54
93
78,241
75 years
24
3.38
94
12,780
75 years
24
3.66
95
10,264
75 years
24
3.66
96
1,052
75 years
24
1.05
97
150,818
98
99
1,652
40 years
1.27
100
48,517
35 years
1
3.34
101
951
0 years
19.51
102
26,209
35 years
1
3.01
103
479
0 years
19.51
104
180,621
40 years
1.32
105
323,056
35 years
1
3.07
106
6,591
0 years
19.51
107
19,434
40 years
1.48
108
27,938
35 years
1
3.26
109
477
0 years
19.51
110
1,270
40 years
3.7
111
30,900
35 years
1
3.74
112
77
0 years
19.51
113
5,726
0 years
5
114
673,898
115
116
97,601
0 years
0.66
117
169,425
60 years
20
1.86
R3
118
2,013,345
43 years
10
2.52
R2
119
873
0 years
19.51
120
15,542
43 years
10
2.52
R2
121
514,149
75 years
19
1.67
R4
122
522,241
37 years
20
3.03
L1.5
123
734,356
68 years
8
1.66
R4
124
40,675
68 years
8
1.66
R4
125
17,385
42 years
2.97
S6
126
20,884
24 years
4.7
L3.5
127
7,891
24 years
4.7
L3.5
128
4,154,367
129
130
24,703
0 years
1.49
131
41,443
50 years
10
2.46
R5
132
26,460
55 years
12
1.9
R3
133
47
0 years
4
134
412,908
50 years
19
2.32
L0.5
135
277,114
45 years
16
2.52
R1
136
6,173
50 years
19
2.32
L0.5
137
3,754
45 years
16
2.52
R1
138
5,333
15 years
7.38
SQ
139
431,175
40 years
72
3.65
R0.5
140
436,890
33 years
67
4.77
R0.5
141
591,814
35 years
18
3.3
R0.5
142
571,354
35 years
16
3.38
R0.5
143
80,848
57 years
1.61
R4
144
63,280
55 years
1.73
R4
145
206,401
51 years
1.83
R2.5
146
117,016
48 years
2.05
R1.5
147
404,944
35 years
21
3.05
L0
148
244,557
27 years
20
4.65
R0.5
149
195,859
35 years
28
3.48
L1.5
150
177,389
30 years
26
4.22
R0.5
151
28,790
15 years
6
8.14
L1
152
41,528
15 years
10
12.43
S6
153
93,017
15 years
6
8.14
L1
154
35,100
15 years
10
12.43
S6
155
39,417
16 years
21
4.73
L0
156
24,454
12 years
22
9.3
R0.5
157
1
25 years
2.01
L3
158
20,970
23 years
33
5
R0.5
159
11,041
20 years
31
8
R0.5
160
4,613,780
161
162
149,791
45 years
8
1.98
R2.5
163
12,024
30 years
3.21
SQ
164
9
27 years
3.44
SQ
165
2,070
55 years
1.88
SQ
166
41,262
43 years
10
2.63
SQ
167
3,073
37 years
3.92
SQ
168
133
25 years
1.84
SQ
169
109,036
24 years
8
4.94
SQ
170
41
24 years
8
4.94
SQ
171
19,365
24 years
8
4.94
SQ
172
8,105
35 years
2.73
SQ
173
344,909
174
15,613,821


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
REGULATORY COMMISSION EXPENSES
  1. Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party.
  2. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years.
  3. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization.
  4. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts.
  5. Minor items (less than $25,000) may be grouped.
EXPENSES INCURRED DURING YEAR AMORTIZED DURING YEAR
CURRENTLY CHARGED TO
Line No.
RegulatoryCommissionDescription
Description (Furnish name of regulatory commission or body the docket or case number and a description of the case)
(a)
RegulatoryExpensesAssessedByRegulatoryCommission
Assessed by Regulatory Commission
(b)
RegulatoryExpensesOfUtility
Expenses of Utility
(c)
RegulatoryCommissionExpensesAmount
Total Expenses for Current Year
(d)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 at Beginning of Year
(e)
NameOfDepartmentRegulatoryCommissionExpensesCharged
Department
(f)
AccountNumberRegulatoryCommissionExpensesCharged
Account No.
(g)
RegulatoryComissionExpensesIncurredAndCharged
Amount
(h)
RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets
Deferred to Account 182.3
(i)
DeferredRegulatoryCommissionExpensesAmortizedInContraAccount
Contra Account
(j)
DeferredRegulatoryCommissionExpensesAmortized
Amount
(k)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 End of Year
(l)
1
Smith Mountain Combination Project #2210 - Proportion of cost of administering the Federal Water Power Act
1,531,695
1,531,695
1,531,695
2
Leesville Hydro Project #2210 - Proportion of cost of administering the Federal Water Power Act
133,361
133,361
133,361
3
Claytor Hydro Project #739 - Proportion of cost of administering the Federal Water Power Act
284,492
284,492
284,492
4
Byllesby Buck Hydro Project #2514 - Proportion of cost of administering the Federal Water Power Act
107,272
107,272
107,272
5
Marmet and London Hydro Project #1175 - Proportion of cost of administering the Federal Water Power Act
111,399
111,399
111,399
6
Winfield Hydro Project #1290 - Proportion of cost of administering the Federal Water Power Act
65,931
65,931
65,931
7
Niagara Hydro Project #2466 - Proportion of cost of administering the Federal Water Power Act
8,430
8,430
8,430
8
Misc Exp - items less than $25,000
290,356
290,356
290,356
9
West Virginia Base Case
773,344
773,344
207,526
595,465
177,879
29,646
10
West Virginia Broadband Filing
54,294
54,294
54,294
11
Virginia Broadband Pilot Filing
170,628
170,628
170,628
12
Virginia Fuel Filing
29,005
29,005
29,005
13
West Virginia Environmental RAC Filing
197,879
197,879
197,879
14
Virginia Energy Efficiency RAC filing
113,124
113,124
113,124
15
Virginia Integrated Resource Plan Filing
48,915
48,915
48,915
16
2020 Virginia Triennial Filing
283,865
283,865
283,865
17
Virginia Clean Economy Act Filing
307,750
307,750
307,750
18
Virginia Triennial Appeal
303,099
303,099
303,099
19
West Virginia Coal Combustion Residuals and Effluent Limitation Guidelines Filing
187,634
187,634
187,634
20
Virginia Environmental RAC Filing
293,183
293,183
293,183
21
Virginia Blue Ridge Petition Filing
59,752
59,752
59,752
22
Virginia Transmission RAC Filing
48,175
48,175
48,175
23
Virginia Generation RAC Filing
47,848
47,848
47,848
24
2023 Virginia Triennial Filing
41,017
41,017
41,017
25
FERC Formula Rate Filing
35,719
35,719
35,719
26
Kanawha River Plant Demolition Filing
31,510
31,510
31,510
27
Virginia Broadband RAC Filing
26,581
26,581
26,581
28
State Commission Fees
5,108,851
5,108,851
5,108,851
46
TOTAL
2,242,580
8,452,529
10,695,109
207,526
10,517,230
177,879
29,646


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
  1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts).
  2. Indicate in column (a) the applicable classification, as shown below:
    Classifications:
    1. Electric R, D and D Performed Internally:
      1. Generation
        1. hydroelectric
          1. Recreation fish and wildlife
          2. Other hydroelectric
        2. Fossil-fuel steam
        3. Internal combustion or gas turbine
        4. Nuclear
        5. Unconventional generation
        6. Siting and heat rejection
      2. Transmission
        1. Overhead
        2. Underground
      3. Distribution
      4. Regional Transmission and Market Operation
      5. Environment (other than equipment)
      6. Other (Classify and include items in excess of $50,000.)
      7. Total Cost Incurred
    2. Electric, R, D and D Performed Externally:
      1. Research Support to the electrical Research Council or the Electric Power Research Institute
      2. Research Support to Edison Electric Institute
      3. Research Support to Nuclear Power Groups
      4. Research Support to Others (Classify)
      5. Total Cost Incurred
  3. Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity.
  4. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e).
  5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year.
  6. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est.""
  7. Report separately research and related testing facilities operated by the respondent.
AMOUNTS CHARGED IN CURRENT YEAR
Line No.
ResearchDevelopmentAndDemonstrationClassification
Classification
(a)
ResearchDevelopmentAndDemonstrationDescription
Description
(b)
ResearchDevelopmentAndDemonstrationCostsIncurredInternally
Costs Incurred Internally Current Year
(c)
ResearchDevelopmentAndDemonstrationCostsIncurredExternally
Costs Incurred Externally Current Year
(d)
AccountNumberForResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Account
(e)
ResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Amount
(f)
ResearchDevelopmentAndDemonstrationExpenditures
Unamortized Accumulation
(g)
1
ELECTRIC UTILITY RESEARCH, DEVELOPMENT &
2
DEMONSTRATION PERFORMED INTERNALLY
3
A(1)b Generation: Fossil - Fuel Steam
Adv. Generation Prog. Management
165,070
165,070
4
3 Item(s) Under $50,000
23,664
23,664
5
A(1)e Generation: Unconventional generation
2 Item(s) Under $50,000
6
A(2) Transmission:
1 Item(s) Under $50,000
13,046
13,046
7
A(3) Distribution:
1 Item(s) Under $50,000
10,274
10,274
8
A(5) Environment: (Other Than Equipment)
1 Item(s) Under $50,000
47,359
47,359
9
A(6) Other:
Corporate Technology Prog Mgmt
127,205
127,205
10
1 Item(s) Under $50,000
39
39
11
A(6)a:
1 Item(s) Under $50,000
72
72
12
A(6)f Other: Metering
1 Item(s) Under $50,000
2,006
2,006
13
A(6)g Research - General:
1 Item(s) Under $50,000
2,694
2,694
14
A(7) TOTAL COST INCURRED INTERNALLY
391,430
391,430
15
ELECTRIC UTILITY RESEARCH, DEVELOPMENT & DEMONSTRATION PERFORMED EXTERNALLY
7 Item(s) Under $50,000
90,283
90,283
16
B(1) Research Support to Elec. Research Council & Elec. Power Research Inst.
EPRI Research Portfolio
1,313,754
1,313,754
17
EPRI Environmental Science
650,517
650,517
18
T Line Robots - Reclass
222,483
222,483
19
Low Carbon Resource Initiative
189,866
189,866
20
IT - EPRI Annual Research Port
66,276
66,276
21
27 Item(s) Under $50,000
99,092
99,092
22
B(4) Research Support to Others
3 Item(s) under $50,000
23,180
23,180
23
B(5) TOTAL COST INCURRED EXTERNALLY
2,655,451
2,655,451


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
DISTRIBUTION OF SALARIES AND WAGES

Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.

Line No.
Classification
(a)
Direct Payroll Distribution
(b)
Allocation of Payroll Charged for Clearing Accounts
(c)
Total
(d)
1
SalariesAndWagesElectricAbstract
Electric
2
SalariesAndWagesElectricOperationAbstract
Operation
3
SalariesAndWagesElectricOperationProduction
Production
25,291,936
4
SalariesAndWagesElectricOperationTransmission
Transmission
88,931
5
SalariesAndWagesElectricOperationRegionalMarket
Regional Market
6
SalariesAndWagesElectricOperationDistribution
Distribution
6,937,073
7
SalariesAndWagesElectricOperationCustomerAccounts
Customer Accounts
6,558,776
8
SalariesAndWagesElectricOperationCustomerServiceAndInformational
Customer Service and Informational
2,780,566
9
SalariesAndWagesElectricOperationSales
Sales
10
SalariesAndWagesElectricOperationAdministrativeAndGeneral
Administrative and General
2,407,593
11
SalariesAndWagesElectricOperation
TOTAL Operation (Enter Total of lines 3 thru 10)
44,064,875
12
SalariesAndWagesElectricMaintenanceAbstract
Maintenance
13
SalariesAndWagesElectricMaintenanceProduction
Production
25,179,103
14
SalariesAndWagesElectricMaintenanceTransmission
Transmission
86,132
15
SalariesAndWagesElectricMaintenanceRegionalMarket
Regional Market
16
SalariesAndWagesElectricMaintenanceDistribution
Distribution
26,580,660
17
SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral
Administrative and General
2,977,006
18
SalariesAndWagesElectricMaintenance
TOTAL Maintenance (Total of lines 13 thru 17)
54,822,901
19
SalariesAndWagesElectricOperationAndMaintenanceAbstract
Total Operation and Maintenance
20
SalariesAndWagesElectricProduction
Production (Enter Total of lines 3 and 13)
50,471,039
21
SalariesAndWagesElectricTransmission
Transmission (Enter Total of lines 4 and 14)
175,063
22
SalariesAndWagesElectricRegionalMarket
Regional Market (Enter Total of Lines 5 and 15)
23
SalariesAndWagesElectricDistribution
Distribution (Enter Total of lines 6 and 16)
33,517,733
24
SalariesAndWagesElectricCustomerAccounts
Customer Accounts (Transcribe from line 7)
6,558,776
25
SalariesAndWagesElectricCustomerServiceAndInformational
Customer Service and Informational (Transcribe from line 8)
2,780,566
26
SalariesAndWagesElectricSales
Sales (Transcribe from line 9)
27
SalariesAndWagesElectricAdministrativeAndGeneral
Administrative and General (Enter Total of lines 10 and 17)
5,384,599
28
SalariesAndWagesElectricOperationAndMaintenance
TOTAL Oper. and Maint. (Total of lines 20 thru 27)
98,887,776
7,439,232
106,327,008
29
SalariesAndWagesGasAbstract
Gas
30
SalariesAndWagesGasOperationAbstract
Operation
31
SalariesAndWagesGasOperationProductionManufacturedGas
Production - Manufactured Gas
32
SalariesAndWagesGasOperationProductionNaturalGas
Production-Nat. Gas (Including Expl. And Dev.)
33
SalariesAndWagesGasOperationOtherGasSupply
Other Gas Supply
34
SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing
Storage, LNG Terminaling and Processing
35
SalariesAndWagesGasOperationTransmission
Transmission
36
SalariesAndWagesGasOperationDistribution
Distribution
37
SalariesAndWagesGasCustomerAccounts
Customer Accounts
38
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational
39
SalariesAndWagesGasSales
Sales
40
SalariesAndWagesGasOperationAdministrativeAndGeneral
Administrative and General
41
SalariesAndWagesGasOperation
TOTAL Operation (Enter Total of lines 31 thru 40)
42
SalariesAndWagesGasMaintenanceAbstract
Maintenance
43
SalariesAndWagesGasMaintenanceProductionManufacturedGas
Production - Manufactured Gas
44
SalariesAndWagesGasMaintenanceProductionNaturalGas
Production-Natural Gas (Including Exploration and Development)
45
SalariesAndWagesGasMaintenanceOtherGasSupply
Other Gas Supply
46
SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing
47
SalariesAndWagesGasMaintenanceTransmission
Transmission
48
SalariesAndWagesGasMaintenanceDistribution
Distribution
49
SalariesAndWagesGasMaintenanceAdministrativeAndGeneral
Administrative and General
50
SalariesAndWagesGasMaintenance
TOTAL Maint. (Enter Total of lines 43 thru 49)
51
SalariesAndWagesGasOperationAndMaintenanceAbstract
Total Operation and Maintenance
52
SalariesAndWagesGasProductionManufacturedGas
Production-Manufactured Gas (Enter Total of lines 31 and 43)
53
SalariesAndWagesGasProductionNaturalGas
Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54
SalariesAndWagesGasOtherGasSupply
Other Gas Supply (Enter Total of lines 33 and 45)
55
SalariesAndWagesGasStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing (Total of lines 31 thru
56
SalariesAndWagesGasTransmission
Transmission (Lines 35 and 47)
57
SalariesAndWagesGasDistribution
Distribution (Lines 36 and 48)
58
SalariesAndWagesGasCustomerAccounts
Customer Accounts (Line 37)
59
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational (Line 38)
60
SalariesAndWagesGasSales
Sales (Line 39)
61
SalariesAndWagesGasAdministrativeAndGeneral
Administrative and General (Lines 40 and 49)
62
SalariesAndWagesGasOperationAndMaintenance
TOTAL Operation and Maint. (Total of lines 52 thru 61)
63
SalariesAndWagesOtherUtilityDepartmentsAbstract
Other Utility Departments
64
SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance
Operation and Maintenance
65
SalariesAndWagesOperationsAndMaintenance
TOTAL All Utility Dept. (Total of lines 28, 62, and 64)
98,887,776
7,439,232
106,327,008
66
SalariesAndWagesUtilityPlantAbstract
Utility Plant
67
SalariesAndWagesUtilityPlantConstructionAbstract
Construction (By Utility Departments)
68
SalariesAndWagesUtilityPlantConstructionElectricPlant
Electric Plant
48,434,542
3,643,684
52,078,226
69
SalariesAndWagesUtilityPlantConstructionGasPlant
Gas Plant
70
SalariesAndWagesUtilityPlantConstructionOther
Other (provide details in footnote):
71
SalariesAndWagesUtilityPlantConstruction
TOTAL Construction (Total of lines 68 thru 70)
48,434,542
3,643,684
52,078,226
72
SalariesAndWagesPlantRemovalAbstract
Plant Removal (By Utility Departments)
73
SalariesAndWagesPlantRemovalElectricPlant
Electric Plant
10,900,317
820,020
11,720,337
74
SalariesAndWagesPlantRemovalGasPlant
Gas Plant
75
SalariesAndWagesPlantRemovalOther
Other (provide details in footnote):
76
SalariesAndWagesPlantRemoval
TOTAL Plant Removal (Total of lines 73 thru 75)
10,900,317
820,020
11,720,337
77
SalariesAndWagesOtherAccountsAbstract
Other Accounts (Specify, provide details in footnote):
78
SalariesAndWagesOtherAccountsDescription
Other Accounts (Specify, provide details in footnote):
79
SalariesAndWagesOtherAccountsDescription
152 - Fuel Stock Undistributed
8,591,762
8,591,762
80
SalariesAndWagesOtherAccountsDescription
154 - Materials and Supplies
81
SalariesAndWagesOtherAccountsDescription
163 - Stores Expense Undistributed
5,137,773
5,137,773
82
SalariesAndWagesOtherAccountsDescription
183 - Prelim Survey
36,855
36,855
83
SalariesAndWagesOtherAccountsDescription
184 - Clearing Accounts
6,728,308
6,728,308
84
SalariesAndWagesOtherAccountsDescription
185 - ODD Temporary Facilities
225,464
225,464
85
SalariesAndWagesOtherAccountsDescription
186 - Misc Deferred Debits
1,499,074
1,499,074
86
SalariesAndWagesOtherAccountsDescription
188 - Research & Development
2,215
2,215
87
SalariesAndWagesOtherAccountsDescription
242 - Misc Current & Accrued Liab
88
SalariesAndWagesOtherAccountsDescription
401 - Operation Expense - Nonassociated
219
219
89
SalariesAndWagesOtherAccountsDescription
426 - Political Activities
395,811
395,811
90
SalariesAndWagesOtherAccountsDescription
91
SalariesAndWagesOtherAccountsDescription
92
SalariesAndWagesOtherAccountsDescription
93
SalariesAndWagesOtherAccountsDescription
94
SalariesAndWagesOtherAccountsDescription
95
SalariesAndWagesOtherAccounts
TOTAL Other Accounts
22,613,051
11,902,936
10,710,115
96
SalariesAndWagesGeneralExpense
TOTAL SALARIES AND WAGES
180,835,686
180,835,686


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
COMMON UTILITY PLANT AND EXPENSES
  1. Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors.
  2. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used.
  3. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation.
  4. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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)
350,465,570
2.1 Net Purchases (Account 555.1)
3 Net Sales (Account 447)
148,544,555
4 Transmission Rights
35,502,675
5 Ancillary Services
5,801,575
6 Other Items (list separately)
7
Congestion
37,377,583
8
Operating Reserves
1,555,354
9
Transmission Purchase Expense
21,282,169
10
Transmission Losses
21,420,123
11
Meter Correction
912,772
12
Inadvertent
108,791
13
Capacity Credits
7,548,753
46 TOTAL
244,217,246


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff.
In columns for usage, report usage-related billing determinant and the unit of measure.
  1. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year.
  2. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year.
  3. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year.
  4. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year.
  5. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period.
  6. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
Amount Purchased for the Year Amount Sold for the Year
Usage - Related Billing Determinant Usage - Related Billing Determinant
Line No.
Type of Ancillary Service
(a)
Number of Units
(b)
Unit of Measure
(c)
Dollar
(d)
Number of Units
(e)
Unit of Measure
(f)
Dollars
(g)
1
Scheduling, System Control and Dispatch
2
Reactive Supply and Voltage
3
Regulation and Frequency Response
4
Energy Imbalance
5
Operating Reserve - Spinning
6
Operating Reserve - Supplement
7
Other
8
Total (Lines 1 thru 7)


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: AncillaryServicesPurchasedNumberOfUnits
The final grandfathered contracts (under the AEP OATT) expired 12/31/2010. Currently, services are provided under the SPP and PJM OATTs.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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: 0
1
January
2
February
3
March
4
Total for Quarter 1
0
0
0
0
0
0
5
April
6
May
7
June
8
Total for Quarter 2
0
0
0
0
0
0
9
July
10
August
11
September
12
Total for Quarter 3
0
0
0
0
0
0
13
October
14
November
15
December
16
Total for Quarter 4
0
0
0
0
0
0
17
Total
0
0
0
0
0
0


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: MonthlyPeakLoadExcludingIsoAndRto
Appalachian Power Company's transmission service is administered through an RTO/ISO and requested

information is not available on an individual operating company basis.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
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: 0
1
January
2
February
3
March
4
Total for Quarter 1
0
0
0
0
0
0
5
April
6
May
7
June
8
Total for Quarter 2
0
0
0
0
0
0
9
July
10
August
11
September
12
Total for Quarter 3
0
0
0
0
0
0
13
October
14
November
15
December
16
Total for Quarter 4
0
0
0
0
0
0
17
Total Year to Date/Year
0
0
0
0
0
0


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2022-05-19
Year/Period of Report

End of:
2021
/
Q4
ELECTRIC ENERGY ACCOUNT

Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.

Line No. Item
(a)
MegaWatt Hours
(b)
Line No. Item
(a)
MegaWatt Hours
(b)
1
SOURCES OF ENERGY
21
DISPOSITION OF ENERGY
2
Generation (Excluding Station Use):
22
Sales to Ultimate Consumers (Including Interdepartmental Sales)
26,845,286
3
Steam
19,279,417
23
Requirements Sales for Resale (See instruction 4, page 311.)
2,800,056
4
Nuclear
24
Non-Requirements Sales for Resale (See instruction 4, page 311.)
4,167,084
5
Hydro-Conventional
602,111
25
Energy Furnished Without Charge
(a)
341,985
6
Hydro-Pumped Storage
403,818
26
Energy Used by the Company (Electric Dept Only, Excluding Station Use)
7
Other
4,431,916
27
Total Energy Losses
2,146,304
8
Less Energy for Pumping
437,239
27.1
Total Energy Stored
9
Net Generation (Enter Total of lines 3 through 8)
24,280,023
28
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES
35,616,745
10
Purchases (other than for Energy Storage)
11,336,722
10.1
Purchases for Energy Storage
0
11
Power Exchanges:
12
Received
0
13
Delivered
0
14
Net Exchanges (Line 12 minus line 13)
0
15
Transmission For Other (Wheeling)
16
Received
17
Delivered
18
Net Transmission for Other (Line 16 minus line 17)
0
19
Transmission By Others Losses
20
TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)
35,616,745


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2022-05-19
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: NonChargedEnergy
Represents Megawatt Hours included in Line 22, Sales to Ultimate Consumers, that were delivered and billed to shopping customers and provided by external suppliers. This total also includes hydropower Megawatt Hours provided free of charge to the Government.
Sales to Ultimate Consumers (374,911)
Hydropower to Government 687 
(374,224)

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
MONTHLY PEAKS AND 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)
EnergyActivity
Total Monthly Energy
(b)
NonRequiredSalesForResaleEnergy
Monthly Non-Requirement Sales for Resale & Associated Losses
(c)
MonthlyPeakLoad
Monthly Peak - Megawatts
(d)
DayOfMonthlyPeak
Monthly Peak - Day of Month
(e)
HourOfMonthlyPeak
Monthly Peak - Hour
(f)
NAME OF SYSTEM: 0
29
January
3,464,932
247,297
5,966
29
8
30
February
3,434,973
493,653
5,975
8
8
31
March
2,654,975
63,293
5,393
8
8
32
April
2,425,438
150,812
4,913
2
8
33
May
2,790,683
533,168
4,842
26
17
34
June
3,236,698
724,443
5,176
29
18
35
July
3,365,867
643,829
5,309
29
17
36
August
3,413,553
645,916
5,363
25
15
37
September
2,539,650
199,584
4,914
14
17
38
October
2,310,350
33,237
4,113
15
17
39
November
2,723,639
59,967
5,335
24
8
40
December
3,255,987
570,781
5,422
9
8
41
Total
35,616,745
4,365,980


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.
Item
(a)
Plant Name:
0
Plant Name:
Amos
Plant Name:
Ceredo
Plant Name:
Clinch River
Plant Name:
Dresden
Plant Name:
Mountaineer
1
PlantKind
Kind of Plant (Internal Comb, Gas Turb, Nuclear)
STEAM
GAS TURBINE
STEAM
COMBINED CYCLE
STEAM
2
PlantConstructionType
Type of Constr (Conventional, Outdoor, Boiler, etc)
CONVENTIONAL
NO BOILER
CONVENTIONAL
OUTDOOR HRSG
OUTDOOR BOILER
3
YearPlantOriginallyConstructed
Year Originally Constructed
1971
2001
1958
2012
1980
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
1973
2001
1961
2012
1980
5
InstalledCapacityOfPlant
Total Installed Cap (Max Gen Name Plate Ratings-MW)
2,963.00
519.18
712.50
669.00
1,320.00
6
NetPeakDemandOnPlant
Net Peak Demand on Plant - MW (60 minutes)
2,933
555
460
667
1,322
7
PlantHoursConnectedToLoad
Plant Hours Connected to Load
5,520
791
761
7,373
6,163
8
NetContinuousPlantCapability
Net Continuous Plant Capability (Megawatts)
0
0
0
0
0
9
NetContinuousPlantCapabilityNotLimitedByCondenserWater
When Not Limited by Condenser Water
2,930
516
465
665
1,320
10
NetContinuousPlantCapabilityLimitedByCondenserWater
When Limited by Condenser Water
2,930
450
455
570
1,305
11
PlantAverageNumberOfEmployees
Average Number of Employees
231
5
36
33
157
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
12,012,357,000
331,156,000
133,135,000
4,100,760,000
7,133,925,000
13
CostOfLandAndLandRightsSteamProduction
Cost of Plant: Land and Land Rights
7,307,834
910,000
501,098
2,286,932
4,554,535
14
CostOfStructuresAndImprovementsSteamProduction
Structures and Improvements
175,039,410
1,652,232
26,934,648
50,145,564
200,760,618
15
CostOfEquipmentSteamProduction
Equipment Costs
3,399,619,485
203,323,571
273,185,799
421,128,110
1,445,722,724
16
AssetRetirementCostsSteamProduction
Asset Retirement Costs
83,276,248
0
4,831,339
0
8,817,858
17
CostOfPlant
Total cost (total 13 thru 20)
3,665,242,977
205,885,804
305,452,885
473,560,607
1,659,855,736
18
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 17/5) Including
1,237.0040
396.5596
428.7058
707.8634
1,257.4665
19
OperationSupervisionAndEngineeringExpense
Production Expenses: Oper, Supv, & Engr
12,552,669
292,470
1,207,400
510,725
5,247,484
20
FuelSteamPowerGeneration
Fuel
302,440,068
18,764,167
(a)
12,438,963
89,846,704
150,802,275
21
CoolantsAndWater
Coolants and Water (Nuclear Plants Only)
0
0
0
0
0
22
SteamExpensesSteamPowerGeneration
Steam Expenses
31,541,666
80,301
3,120,010
189,270
15,601,017
23
SteamFromOtherSources
Steam From Other Sources
0
0
0
0
0
24
SteamTransferredCredit
Steam Transferred (Cr)
0
0
0
0
0
25
ElectricExpensesSteamPowerGeneration
Electric Expenses
165,461
556,276
37,891
0
0
26
MiscellaneousSteamPowerExpenses
Misc Steam (or Nuclear) Power Expenses
7,102,487
199,382
1,112,584
3,167,981
7,939,994
27
RentsSteamPowerGeneration
Rents
27,093
1
0
0
12,008
28
Allowances
Allowances
97,038
0
466,537
156
48,342
29
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
Maintenance Supervision and Engineering
310,606
0
3,802
588,717
1,460,300
30
MaintenanceOfStructuresSteamPowerGeneration
Maintenance of Structures
1,974,018
0
967,376
130,311
1,158,109
31
MaintenanceOfBoilerPlantSteamPowerGeneration
Maintenance of Boiler (or reactor) Plant
30,316,625
3
1,796,430
759,273
14,636,160
32
MaintenanceOfElectricPlantSteamPowerGeneration
Maintenance of Electric Plant
6,975,232
237,409
785,947
3,380,560
2,201,010
33
MaintenanceOfMiscellaneousSteamPlant
Maintenance of Misc Steam (or Nuclear) Plant
6,633,532
0
1,007,704
2,047,814
2,111,958
34
PowerProductionExpensesSteamPower
Total Production Expenses
0
400,136,495
20,130,009
22,944,644
100,621,511
201,218,657
35
ExpensesPerNetKilowattHour
Expenses per Net kWh
0.0333
0.0608
0.1723
0.0245
0.0282
35
FuelKindAxis
Plant Name
Amos
Amos
Ceredo
Clinch River
Dresden
Mountaineer
Mountaineer
36
FuelKind
Fuel Kind
Coal
Oil
Gas
Gas
Gas
Coal
Oil
37
FuelUnit
Fuel Unit
T
bbl
Mcf
Mcf
Mcf
T
bbl
38
QuantityOfFuelBurned
Quantity (Units) of Fuel Burned
4,839,623
94,027
3,713,406
1,598,300
26,321,820
2,779,824
27,784
39
FuelBurnedAverageHeatContent
Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
12,256
137,063
1,089,000
1,034,000
1,062,000
12,523
137,173
40
AverageCostOfFuelPerUnitAsDelivered
Avg Cost of Fuel/unit, as Delvd f.o.b. during year
53.634
90.787
5.046
7.784
3.436
47.489
81.061
41
AverageCostOfFuelPerUnitBurned
Average Cost of Fuel per Unit Burned
54.373
88.905
5.053
7.751
3.431
47.527
77.921
42
AverageCostOfFuelBurnedPerMillionBritishThermalUnit
Average Cost of Fuel Burned per Million BTU
2.218
15.444
4.640
7.496
3.231
1.898
13.525
43
AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Average Cost of Fuel Burned per kWh Net Gen
0.022
0.000
0.057
0.093
0.022
0.019
0.000
44
AverageBritishThermalUnitPerKilowattHourNetGeneration
Average BTU per kWh Net Generation
9,921.000
0.000
12,215.000
12,197.000
6,821.000
9,782.000
0.000


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: FuelSteamPowerGeneration
Deferred Fuel expenses totaling $(170,684,039) are not included in the Fuel totals that are broken down by generating plants. Deferred fuel expenses for Virginia and West Virginia were $(125,226,589) and $(45,457,450) respectively.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
Hydroelectric Generating Plant Statistics
  1. Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available specifying period.
  4. If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
FERC Licensed Project No.
0
Plant Name:
BUCK
FERC Licensed Project No.
0
Plant Name:
BYLLESBY
FERC Licensed Project No.
0
Plant Name:
CLAYTOR
FERC Licensed Project No.
0
Plant Name:
LEESVILLE
FERC Licensed Project No.
0
Plant Name:
LONDON
FERC Licensed Project No.
0
Plant Name:
MARMET
FERC Licensed Project No.
0
Plant Name:
WINFIELD
1
PlantKind
Kind of Plant (Run-of-River or Storage)
STORAGE
STORAGE
STORAGE
STORAGE
RUN OF RIVER
RUN OF RIVER
RUN OF RIVER
2
PlantConstructionType
Plant Construction type (Conventional or Outdoor)
CONVENTIONAL
CONVENTIONAL
CONVENTIONAL
OUTDOOR
CONVENTIONAL
CONVENTIONAL
CONVENTIONAL
3
YearPlantOriginallyConstructed
Year Originally Constructed
1912
1912
1939
1964
1935
1935
1938
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
1912
1912
1939
1964
1935
1935
1938
5
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
10.7
21.6
75.0
40.0
14.4
14.4
14.8
6
NetPeakDemandOnPlant
Net Peak Demand on Plant-Megawatts (60 minutes)
10
13
78
49
18
12
22
7
PlantHoursConnectedToLoad
Plant Hours Connect to Load
8,219
4,814
5,621
1,940
7,231
6,948
8,370
8
NetPlantCapabilityAbstract
Net Plant Capability (in megawatts)
9
NetPlantCapabilityUnderMostFavorableOperatingConditions
(a) Under Most Favorable Oper Conditions
11
23
88
48
19
20
24
10
NetPlantCapabilityUnderMostAdverseOperatingConditions
(b) Under the Most Adverse Oper Conditions
11
PlantAverageNumberOfEmployees
Average Number of Employees
3
5
1
1
3
4
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
38,270,000
35,181,000
234,622,000
61,019,000
59,702,000
50,159,000
114,210,000
13
CostOfPlantAbstract
Cost of Plant
14
CostOfLandAndLandRightsHydroelectricProduction
Land and Land Rights
170,420
1,612,350
1,784,759
21,043
4,100
15
CostOfStructuresAndImprovementsHydroelectricProduction
Structures and Improvements
569,860
1,216,147
3,863,364
3,838,701
616,623
946,292
2,754,498
16
CostOfReservoirsDamsAndWaterwaysHydroelectricProduction
Reservoirs, Dams, and Waterways
7,895,918
7,441,024
12,713,953
12,110,548
1,696,220
1,880,489
2,767,066
17
EquipmentCostsHydroelectricProduction
Equipment Costs
5,396,468
(a)
11,541,773
10,343,031
8,862,027
10,820,120
11,590,411
11,223,913
18
CostOfRoadsRailroadsAndBridgesHydroelectricProduction
Roads, Railroads, and Bridges
3,437
31,799
80,790
48,853
1,275
23,567
19
AssetRetirementCostsHydroelectricProduction
Asset Retirement Costs
72,046
362,724
196,310
93,690
125,314
137,743
20
CostOfPlant
Total cost (total 13 thru 20)
13,865,683.00
20,441,410
28,927,221
26,873,135
13,296,549
14,547,881.00
16,906,787
21
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 20 / 5)
1,295.9
946.3616
385.6963
671.8284
923.3715
1,010.3
1,142.3505
22
ProductionExpensesAbstract
Production Expenses
23
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
35,873
68,997
310,048
63,397
62,295
198,425
107,125
24
WaterForPower
Water for Power
308
502
7,743
7,785
7,742
25
HydraulicExpenses
Hydraulic Expenses
2,455
2,998
434,829
187,352
16,902
8,682
13,587
26
ElectricExpensesHydraulicPowerGeneration
Electric Expenses
12,999
13,982
80,594
20,727
20,279
17,038
38,794
27
MiscellaneousHydraulicPowerGenerationExpenses
Misc Hydraulic Power Generation Expenses
71,861
96,702
593,037
116,544
238,024
322,872
240,851
28
RentsHydraulicPowerGeneration
Rents
4,583
90,513
90,511
176,899
29
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
Maintenance Supervision and Engineering
1,947
8,823
55,378
3,105
3,563
4,488
13,771
30
MaintenanceOfStructuresHydraulicPowerGeneration
Maintenance of Structures
15,463
32,013
359,582
789,283
73,652
179,109
406,195
31
MaintenanceOfReservoirsDamsAndWaterways
Maintenance of Reservoirs, Dams, and Waterways
189,528
1,164,654
312,364
193,967
114,221
149,137
192,155
32
MaintenanceOfElectricPlantHydraulicPowerGeneration
Maintenance of Electric Plant
39,453
121,795
207,288
81,903
310,352
86,265
58,715
33
MaintenanceOfMiscellaneousHydraulicPlant
Maintenance of Misc Hydraulic Plant
1,118
3,126
24,232
15,771
22,838
11,919
9,833
34
PowerProductionExpensesHydraulicPower
Total Production Expenses (total 23 thru 33)
370,697
1,513,398
2,382,437
1,472,049
960,382
1,076,231
1,265,667
35
ExpensesPerNetKilowattHour
Expenses per net kWh
0.0097
0.0430
0.0102
0.0241
0.0161
0.0215
0.0111


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: EquipmentCostsHydroelectricProduction
Equipment cost amount also includes $5,726,248.80 of battery storage investment in account 34800.

Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
Pumped Storage Generating Plant Statistics
  1. Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available, specifying period.
  4. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes.
  7. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
FERC Licensed Project No.
0
Plant Name:
SMITH MOUNTAIN
1
PlantConstructionType
Type of Plant Construction (Conventional or Outdoor)
OUTDOOR
2
YearPlantOriginallyConstructed
Year Originally Constructed
1965
3
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
1980
4
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
647
5
NetPeakDemandOnPlant
Net Peak Demaind on Plant-Megawatts (60 minutes)
0
597
6
PlantHoursConnectedToLoad
Plant Hours Connect to Load While Generating
0
848
7
NetContinuousPlantCapability
Net Plant Capability (in megawatts)
0
565
8
PlantAverageNumberOfEmployees
Average Number of Employees
16
9
NetGenerationExcludingPlantUse
Generation, Exclusive of Plant Use - kWh
0
403,818,000
10
EnergyUsedForPumping
Energy Used for Pumping
437,239,000
11
NetOutputForLoad
Net Output for Load (line 9 - line 10) - Kwh
0
33,421,000
12
CostOfPlantAbstract
Cost of Plant
13
CostOfLandAndLandRightsPumpedStoragePlant
Land and Land Rights
6,168,815
14
CostOfStructuresAndImprovementsPumpedStoragePlant
Structures and Improvements
0
16,356,288
15
CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Reservoirs, Dams, and Waterways
0
32,125,207
16
CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant
Water Wheels, Turbines, and Generators
0
78,241,314
17
CostOfAccessoryElectricEquipmentPumpedStoragePlant
Accessory Electric Equipment
0
12,759,209
18
CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant
Miscellaneous Powerplant Equipment
0
10,305,504
19
CostOfRoadsRailroadsAndBridgesPumpedStoragePlant
Roads, Railroads, and Bridges
0
1,052,133
20
AssetRetirementCostsPumpedStoragePlant
Asset Retirement Costs
0
1,687,175
21
CostOfPlant
Total cost (total 13 thru 20)
158,695,645
22
CostPerKilowattOfInstalledCapacity
Cost per KW of installed cap (line 21 / 4)
245.2792
23
ProductionExpensesAbstract
Production Expenses
24
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
0
752,152
25
WaterForPower
Water for Power
0
26
PumpedStorageExpenses
Pumped Storage Expenses
0
315,831
27
ElectricExpensesPumpedStoragePlant
Electric Expenses
0
190,536
28
MiscellaneousPumpedStoragePowerGenerationExpenses
Misc Pumped Storage Power generation Expenses
0
1,645,467
29
RentsPumpedStoragePlant
Rents
0
30
MaintenanceSupervisionAndEngineeringPumpedStoragePlant
Maintenance Supervision and Engineering
0
147,785
31
MaintenanceOfStructuresPumpedStoragePlant
Maintenance of Structures
0
875,664
32
MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Maintenance of Reservoirs, Dams, and Waterways
0
459,053
33
MaintenanceOfElectricPlantPumpedStoragePlant
Maintenance of Electric Plant
0
1,779,180
34
MaintenanceOfMiscellaneousPumpedStoragePlant
Maintenance of Misc Pumped Storage Plant
0
38,282
35
PowerProductionExpenseBeforePumpingExpenses
Production Exp Before Pumping Exp (24 thru 34)
6,203,950
36
PumpingExpenses
Pumping Expenses
12,179,288
37
PowerProductionExpensesPumpedStoragePlant
Total Production Exp (total 35 and 36)
18,383,238
38
ExpensesPerNetKilowattHour
Expenses per kWh (line 37 / 9)
0.0455
39
ExpensesPerNetKilowattHourGenerationAndPumping
Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
GENERATING PLANT STATISTICS (Small Plants)
  1. Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating).
  2. Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote.
  3. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402.
  4. If net peak demand for 60 minutes is not available, give the which is available, specifying period.
  5. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
Production Expenses
Line No.
PlantName
Name of Plant
(a)
YearPlantOriginallyConstructed
Year Orig. Const.
(b)
InstalledCapacityOfPlant
Installed Capacity Name Plate Rating (MW)
(c)
NetPeakDemandOnPlant
Net Peak Demand MW (60 min)
(d)
NetGenerationExcludingPlantUse
Net Generation Excluding Plant Use
(e)
CostOfPlant
Cost of Plant
(f)
PlantCostPerMw
Plant Cost (Incl Asset Retire. Costs) Per MW
(g)
OperatingExpensesExcludingFuel
Operation Exc'l. Fuel
(h)
FuelProductionExpenses
Fuel Production Expenses
(i)
MaintenanceProductionExpenses
Maintenance Production Expenses
(j)
FuelKind
Kind of Fuel
(k)
FuelCostPerMmbtus
Fuel Costs (in cents (per Million Btu)
(l)
GenerationType
Generation Type
(m)
1
HYDRO-ELECTRIC
2
Niagara - Project #2466
1906
3.60
2.3
8,945,000
8,904,780
40,172
123,188
3
TOTAL HYDRO (Small Plants)
8,945,000
8,904,780


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
ENERGY STORAGE OPERATIONS (Large Plants)
  1. Large Plants are plants of 10,000 Kw or more.
  2. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location.
  3. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage.
  4. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services.
  5. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy.
  6. In column (k) report the MWHs sold.
  7. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity.
  8. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power.
  9. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.
Name of the Energy Storage Project
(a)
Functional Classification
(b)
Location of the Project
(c)
MWHs
(d)
MWHs delivered to the grid to support Production
(e)
MWHs delivered to the grid to support Transmission
(f)
MWHs delivered to the grid to support Distribution
(g)
MWHs Lost During Conversion, Storage and Discharge of Energy Production
(h)
MWHs Lost During Conversion, Storage and Discharge of Energy Transmission
(i)
MWHs Lost During Conversion, Storage and Discharge of Energy Distribution
(j)
MWHs Sold
(k)
Revenues from Energy Storage Operations
(l)
Power Purchased for Storage Operations (555.1) (Dollars)
(m)
Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars)
(n)
Other Costs Associated with Self-Generated Power (Dollars)
(o)
Project Costs included in
(p)
Production (Dollars)
(q)
Transmission (Dollars)
(r)
Distribution (Dollars)
(s)
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


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
TRANSMISSION LINE STATISTICS
  1. Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts.
  2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page.
  3. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.
  4. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line.
  5. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated.
  6. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g).
  7. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company.
  8. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company.
  9. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
DESIGNATION VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase) LENGTH (Pole miles) - (In the case of underground lines report circuit miles) COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way) EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
OperatingVoltageOfTransmissionLine
Operating
DesignedVoltageOfTransmissionLine
Designated
SupportingStructureOfTransmissionLineType
Type of Supporting Structure
LengthForStandAloneTransmissionLines
On Structure of Line Designated
LengthForTransmissionLinesAggregatedWithOtherStructures
On Structures of Another Line
NumberOfTransmissionCircuits
Number of Circuits
SizeOfConductorAndMaterial
Size of Conductor and Material
CostOfLandAndLandRightsTransmissionLines
Land
ConstructionAndOtherCostsTransmissionLines
Construction Costs
OverallCostOfTransmissionLine
Total Costs
OperatingExpensesOfTransmissionLine
Operation Expenses
MaintenanceExpensesOfTransmissionLine
Maintenance Expenses
RentExpensesOfTransmissionLine
Rents
OverallExpensesOfTransmissionLine
Total Expenses
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
1
STATE OF TENNESSEE
STATE OF TENNESSEE
2
0188 BRADFORD, VA
SULLIVAN, TN
500
500
0
0
1
2049KCM ACAR
3
0400 CANE RIVER, TN CIR-A
NAGEL, TN
230
230
46
0
1
1590KCM ACSR
4
0400 CANE RIVER, TN CIR-B
NAGEL, TN
230
230
1
45
1
1590KCM ACSR
5
0351 CLINCH RIVER, VA
NAGEL, TN
138
138
0
0
1
1590KCM ACSR
6
0353 NAGEL, TN
REEDY CREEK, TN
138
138
0
0
1
1590KCM ACSR
7
0349 BROADFORD, VA
NAGEL, TN
138
138
13
0
1
397KCM ACSR
8
0349 BROADFORD, VA
NAGEL, TN
0
0
0
0
0
9
0355 NAGEL, TN
WEST KINGSPORT, TN
138
138
0
1
1
556KCM
10
0355 NAGEL, TN
WEST KINGSPORT, TN
0
0
0
0
0
11
0176 NORTH BRISTOL, VA
WEST KINGSPORT, VA
138
138
6
11
1
397KCM ACSR
12
0176A HOLSTON, TN
REEDY CREEK, TN
138
138
0
6
1
397KCM ACSR
13
0179 BOONE DAM, TN
HOLSTON, TN
138
138
0
0
1
636KCM ACSR
14
0179 BOONE DAM, TN
HOLSTON, TN
0
0
8
0
0
15
0180 HOLSTON, TN
WALTERS, NC
138
138
65
0
1
250KCM CU
16
0180 HOLSTON, TN
WALTERS, NC
138
138
0
0
1
1033KCM ACSR
17
0570 SALTVILLE
KINGSPORT (TN)
138
138
17
0
2
397.5KCM ACSR
18
STATE OF VIRGINIA
STATE OF VIRGINIA
0
0
19
0186 BAKER, KY
BROADFORD, VA
765
765
0
0
1
954KCM ACSR
20
0186 BAKER, KY
BROADFORD, VA
0
0
47
0
0
21
0187 BROADFORD, VA
JACKSONS FERRY, VA
765
765
49
0
1
954KCM ACSR
22
0253 CLOVERDALE, VA
JACKSONS FERRY, VA
765
765
65
0
1
954KCM ACSR
23
0310 CLOVERDALE, VA
JOSHUA FALLS, VA
765
765
57
0
1
1351KCM ACSR
24
0406 JACKSON FERRY
WYOMING
765
765
57
0
1
795 KCM ACSR
25
0334 AXTON, VA
JACKSONS FERRY, VA
765
765
73
0
1
1351KCM ACSR
26
0181 BROADFORD, VA
SULLIVAN, TN
500
500
33
0
1
2049KCM ACAR
27
0001CLOVERDALE, VA
LEXINGTON, VA
500
500
36
0
1
2-1780KCM ACSS
28
0001 CLOVERDALE
LEXINGTON, VA
500
500
0
0
1
2-1780kcm ACSS
29
0182 JACKSONS FERRY, VA
MCGUIRE, NC
500
500
26
0
1
2049KCM ACAR
30
0008A KANAWHA, WV
MATT FUNK, VA
345
345
8
0
1
1563KCM ACAR
31
0008A KANAWHA, WV
MATT FUNK, VA
0
0
34
0
0
32
0008 CLOVERDALE, VA
MATT FUNK, VA
345
345
0
8
1
954 KCM ACSR
33
0008 CLOVERDALE, VA
MATT FUNK, VA
0
0
19
0
0
34
0142 EAST DANVILLE NO. 1,VA
ROXBORO, NC
230
230
8
0
1
1590KCM ACSR
35
0142 EAST DANVILLE NO. 2,VA
ROXBORO, NC
230
230
0
8
1
1590KCM ACSR
36
0417 BAILEYSVILLE, WV
HALES BRANCH, VA
138
138
0
0
1
636KCM ACSR
37
0417 BAILEYSVILLE, WV
HALES BRANCH, VA
0
0
6
0
0
38
0054 GARDEN CREEK, VA
HALES BRANCH, VA
138
138
0
0
1
636KCM ACSR
39
0054 GARDEN CREEK, VA
HALES BRANCH, VA
0
0
7
0
0
40
0409 LOONEY CREEK TAP, VA
138
138
10
0
1
795KCM ACSR
41
0434 GRASSY CREEK, VA
HALES BRANCH, VA
138
138
0
0
2
1033.5KCM ACSR
42
0434 GRASSY CREEK, VA
HALES BRANCH, VA
138
138
6
0
1
795KCM ACSR
43
0434 GRASSY CREEK, VA
HALES BRANCH, VA
0
0
2
0
0
44
0110 CLAYTOR, VA
MATT FUNK, VA
138
138
30
0
1
397KCM ACSR
45
0110 CLAYTOR, VA
MATT FUNK, VA
138
138
0
0
1
556KCM ACSR
46
0112 MATT FUNK, VA
ROANOKE, VA
138
138
13
5
1
397KCM ACSR
47
0113 CLAYTOR, VA
HANCOCK, VA
138
138
0
39
1
397KCM ACSR
48
0114 HANCOCK, VA
ROANOKE, VA
138
138
5
4
1
397KCM ACSR
49
0229 MERRIMAC TAP, VA
138
138
7
0
1
556KCM ACSR
50
0138 COLLINSVILLE
TAP LINE
138
138
0
0
0
51
8161 CVEC
SCOTTSVILLE
46
138
1
0
1
52
0422 JACKSONS FERRY, VA
PEAK CREEK, VA
138
138
13
0
1
795KCM ACSR
53
0422 JACKSONS FERRY, VA
PEAK CREEK, VA
138
138
1
0
0
954KCM ACSR
54
0129 PHILPOTT TAP, VA
138
138
0
0
1
4/0KCM ACSR
55
0248 CLAYTOR, VA
FIELDALE
138
138
0
0
1
556KCM ACSR
56
0248 CLAYTOR, VA
FIELDALE
0
0
38
0
0
57
0249 FIELDALE, VA
WEST BASSETT, VA
138
138
0
0
1
556KCM ACSR
58
0249 FIELDALE, VA
WEST BASSETT, VA
0
0
6
0
0
59
0120 BEAVER CREEK, KY
CLINCH RIVER, VA
138
138
26
0
1
636KCM ACSR
60
0120 BEAVER CREEK, KY
CLINCH RIVER, VA
138
138
0
0
0
636KCM ACSR
61
0122 CLINCH RIVER, VA
FREMONT, VA
138
138
0
18
1
636KCM ACSR
62
0123 BEAVER CREEK, KY
FREMONT, VA
138
138
0
9
1
636KCM ACSR
63
0289 COOPER RIDGE LOOP, VA
138
138
0
0
1
636KCM ACSR
64
0350 CLINCH RIVER, VA
NAGEL, TN
138
138
5
37
1
636KCM ACSR
65
0352 NAGEL, TN
REEDY CREEK, TN
138
138
0
5
1
556KCM ACSR
66
0365 DICKENS TAP
138
138
3
0
1
795KCM ACSR
67
0259A EAST DANVILLE, WV
EAST MONUMENT
138
138
4
0
0
68
0125 CLINCH RIVER, VA
MORELAND DRIVE, TN
138
138
49
0
1
636KCM ACSR
69
0148 CLINCH RIVER, VA
SALTVILLE #1A, VA
138
138
0
25
1
636KCM ACSR
70
0148 CLINCH RIVER, VA
SALTVILLE #1B, VA
138
138
26
0
1
1033KCM ACSR
71
0256 LEBANON 138KV TAP VA
138
138
0
0
1
336KCM ACSR
72
7539 DAN, VA
CAROLINA
138
138
0
0
0
73
0154 CLINCH RIVER, VA
SALTVILLE #2, VA
138
138
3
40
1
397KCM ACSR
74
0193 BROADFORD, VA
SALTVILLE NO.2, VA
138
138
5
0
2
795KCM ACSR
75
0191 BROADFORD, VA
NAGEL, TN
138
138
45
0
1
397KCM ACSR
76
0354 NAGEL, TN
WEST KINGSPORT, TN
138
138
0
5
1
1590KCM ACSR
77
0361 CLINCH RIVER, VA
SPRING CREEK, VA
138
138
18
4
1
636KCM ACSR
78
0192 NORTH BRISTOL, VA
SPRING CREEK, VA
138
138
0
9
1
795 KCM ACSR
79
0153 NORTH BRISTOL, VA
WEST KINGSPORT, VA
138
138
0
4
1
397KCM ACSR
80
0167 CLINCH RIVER, VA
GARDEN CREEK, VA
138
138
2
0
1
636KCM ACSR
81
0167 CLINCH RIVER, VA
GARDEN CREEK, VA
0
0
22
0
0
82
0298 FLETCHERS RIDGE TAP,VA
138
138
0
0
1
300KCM CU
83
0313 SKEGGS BRANCH, VA
138
138
0
0
1
397KCM ACSR
84
0167A CLINCHFIELD LOOP SITE
138
138
0
0
1
636KCM ACSR
85
0416 CLOVERDALE, VA
HUNTINGTON COURT, VA
138
138
6
0
1
795KCM ACSR
86
0124 CLOVERDALE, VA
SMITH MOUNTAIN, VA
138
138
32
0
1
556KCM ACSR
87
0141 DANVILLE B CIR, VA
EAST DANVILLE, VA
138
138
0
3
1
336KCM ACSR
88
1020 CLINCH RIVER
VIRGINA CITY
138
138
0
0
0
89
0358 AXTON, VA
DANVILLE #1-A, VA
138
138
0
16
1
336 KCM ACSR
90
0358 AXTON, VA
DANVILLE #1-A, VA
138
138
0
0
1
1033.5 ACSR
91
0359 AXTON, VA
MARTINSVILLE, VA
138
138
11
0
1
966KCM ACSR
92
0135 AXTON, VA
DANVILLE #2, VA
138
138
16
0
1
336KCM ACSR
93
0135 AXTON, VA
DANVILLE #2, VA
0
0
3
0
0
94
0135 AXTON, VA
DANVILLE #2, VA
138
138
1
0
1
795KCM SSAC
95
0135 AXTON, VA
DANVILLE #2, VA
0
0
17
0
0
96
0146 FIELDDALE, VA
RIDGEWAY, VA
138
138
10
0
1
397KCM ACSR
97
0300 DAN RIVER, NC
RIDGEWAY, VA
138
138
4
0
1
397KCM ACSR
98
0300 DAN RIVER, NC
RIDGEWAY, VA
138
138
0
0
1
397KCM ACSR
99
0300 DAN RIVER, NC
RIDGEWAY, VA
138
138
0
0
1
1033KCM ACSR
100
0391 SHEFFIELD LOOP
138
138
0
0
1
795KCM ACSR
101
0025 GLEN LYN, VA (A)
SOUTH PRINCETON, WV
138
138
0
0
1
1590KCM ACSR
102
0025 GLEN LYN, VA (B)
SOUTH PRINCETON, WV
138
138
0
0
1
1590KCM ACSR
103
0058 GLEN LYN, VA
WYTHE, VA
138
138
29
0
1
556KCM ACSR
104
0058 GLEN LYN, VA
WYTHE, VA
0
0
1
0
0
1590KCM ACSR
105
0058 GLEN LYN, VA
WYTHE, VA
138
138
1
29
1
556KCM ACSR
106
0375 PROGRESS PARK EXT
138
138
3
0
1
1590KCM ACSR
107
0427 EVINGTON 138KV TAP VA
138
138
0
0
0
397KCM ACSR
108
0063 BROADFORD, VA
SALTVILLE NO.1A&1B, VA
138
138
4
4
2
795KCM ACSR
109
0063 BROADFORD, VA
SALTVILLE NO.1A&1B, VA
138
138
0
4
2
556KCM ACSR
110
0063 BROADFORD, VA
SALTVILLE NO.1A&1B, VA
138
138
0
0
2
795KCM ACSR
111
0061B RURAL RETREAT
LOOP, WV
138
138
0
0
1
795KCM ACSR
112
0333 BROADFORD, VA
RICHLANDS, VA
138
138
14
0
1
1033KCM ACSR
113
0368 CLAY POOL HILL LOOP,VA
138
138
0
0
1
1033KCM ACSR
114
0241A HUFFMAN, VA
JACKSONS FERRY, VA
138
138
0
2
1
1033KCM ACSR
115
0241A HUFFMAN, VA
JACKSONS FERRY, VA
0
0
8
0
0
116
0241 HUFFMAN, VA
WYTHE, VA
138
138
2
1
1
795KCM ACSR
117
0241 HUFFMAN, VA
WYTHE, VA
138
138
37
0
1
795KCM ACSR
118
0061 ATKINS, VA
BROADFORD CIR A, VA
138
138
20
0
1
556KCM ACSR
119
0061 ATKINS, VA
BROADFORD CIR B, VA
138
138
0
16
1
556KCM ACSR
120
0063 ATKINS, VA
WYTHE CIR A, VA
138
138
22
0
1
1590KCM ACSR
121
0063 ATKINS, VA
WYTHE CIR B, VA
138
138
0
21
1
556KCM ACSR
122
0433 HUFFMAN, VA
WILLIS GAP, VA
138
138
14
0
1
1033KCM ACSR
123
0106 CLAYTOR, VA
GLEN LYN #1, VA
138
138
26
0
1
397KCM ACSR
124
0106 CLAYTOR, VA
GLEN LYN #2, VA
138
138
0
26
1
397KCM ACSR
125
0109 MORGANS CUT LOOP, VA
138
138
0
0
1
397KCM ACSR
126
0117 HANCOCK, VA
MATT FUNK, VA
138
138
11
0
1
556KCM ACSR
127
0118 CLOVERDALE, VA
MATT FUNK, VA
138
138
0
21
1
636KCM ACSR
128
0119 CLOVERDALE, VA
GLEN LYN, VA
138
138
20
39
1
556KCM ACSR
129
0119 CLOVERDALE, VA
GLEN LYN, VA
138
138
0
0
1
556KCM ACSR
130
0119 CLOVERDALE, VA
GLEN LYN, VA
138
138
0
0
2
795KCM ACSR
131
0374 PATRIOT CENTRE EXT
138
138
3
0
1
795KCM ACSR
132
0367 BURLINGTON HEIGHTS LOO
138
138
0
0
1
795KCM ACSR
133
0383 WEST SALEM LOOP, VA
138
138
0
0
1
795KCM ACSR
134
0116 CELANESE, VA
GLEN LYN, VA
138
138
4
0
1
556KCM ACSR
135
0116 CELANESE, VA
GLEN LYN, VA
0
0
4
0
0
136
0462 MATT FUNK EXT
138
138
5
0
0
1590 KCM ACSR
137
0115 CELANESE, VA
MATT FUNK, VA
138
138
34
0
1
556KCM ACSR
138
0115 CELANESE, VA
MATT FUNK, VA
138
138
2
0
1
556KCM ACSR
139
0115 CELANESE, VA
MATT FUNK, VA
138
138
0
0
2
1033KCM ACSR
140
0038 BRADLEY CIR-A, WV
GLEN LYN-HINTON, VA
138
138
0
4
1
556KCM ACSR
141
0224 BRADLEY CIR-B, WV
GLEN LYN-HINTON
138
138
4
0
1
556KCM ACSR
142
0145 ALTAVISTA, VA
REUSENS, VA
138
138
5
0
1
397KCM ACSR
143
0145 ALTAVISTA, VA
REUSENS, VA
138
138
20
0
1
397KCM ACSR
144
0311 OPOSSUM CREEK, VA
REUSENS, VA
138
138
9
5
1
397KCM ACSR
145
0311 OPOSSUM CREEK, VA
REUSENS, VA
138
138
0
0
2
1033KCM ACSR
146
0312 BRUSH TAVERN TAP, VA
138
138
3
0
1
556KCM ACSR
147
0145A BOONSBORO LOOP, VA
138
138
0
0
1
397KCM ACSR
148
0394 GRAVES MILLS LOOP, VA
138
138
0
0
1
795KCM ACSR
149
7119 HANCOCK, VA
ROANOKE, VA TOWER 198
138
138
0
0
0
150
0156A CLIFFORD, VA
REUSENS, VA
138
138
23
4
1
795KCM ACSR
151
0156 CLIFFORD, VA
SCOTTSVILLE, VA
138
138
29
0
1
397KCM ACSR
152
0156B BREMO, VA
SCOTTSVILLE, VA
138
138
7
0
1
397KCM ACSR
153
0170 OPOSSUM CREEK, VA
SMITH MOUNTAIN, VA
138
138
15
0
1
556KCM ACSR
154
0170 OPOSSUM CREEK, VA
SMITH MOUNTAIN, VA
0
0
19
0
0
155
0170 LEESVILLE, VA
SMITH MOUNTAIN, VA
138
138
0
8
1
556KCM ACSR
156
0173 ALTAVISTA, VA
LEESVILLE, VA
138
138
0
5
1
556KCM ACSR
157
0173 ALTAVISTA, VA
LEESVILLE, VA
0
0
3
0
0
158
0258 OPOSSUM CREEK, VA
PEAKSVIEW, VA
138
138
0
0
1
556KCM ACSR
159
0258 OPOSSUM CREEK, VA
PEAKSVIEW, VA
138
138
1
0
1
556KCM ACSR
160
0258 OPOSSUM CREEK, VA
PEAKSVIEW, VA
138
138
0
0
1
556KCM ACSR
161
0309 EAST LYNCHBURG, VA
OPOSSUM CREEK, VA
138
138
3
0
1
1590KCM ACSR
162
0322 JOSHUA FALLS, VA
REUSENS A&B, VA
138
138
7
0
2
556KCM ACSR
163
0322 JOSHUA FALLS, VA
REUSENS A&B, VA
138
138
0
0
2
1590KCM ACSR
164
0322 JOSHUA FALLS, VA
REUSENS A&B, VA
138
138
3
0
1
1590KCM ACSR
165
0322 JOSHUA FALLS, VA
REUSENS A&B, VA
138
138
0
0
1
1590KCM ACSR
166
0322 JOSHUA FALLS, VA
REUSENS A&B, VA
138
138
0
0
2
1590KCM ACSR
167
0321 JOSHUA FALLS, VA
OPOSSUM CREEK, VA
138
138
0
7
1
1590KCM ACSR
168
0320 EAST LYNCHBURG, VA
JOSHUA FALLS, VA
138
138
3
0
2
1590KCM ACSR
169
0320 EAST LYNCHBURG, VA
JOSHUA FALLS, VA
138
138
1
0
1
1590KCM ACSR
170
0366 RUSTBURG TAP, VA
138
138
4
0
1
795KCM ACSR
171
0395 MONEL LOOP, VA
138
138
0
0
1
1590KCM ACSR
172
0399 TANK HILL TAP, VA
138
138
1
0
1
795KCM ACSR
173
0161 CLOVERDALE, VA
ROANOKE, VA
138
138
16
0
1
556KCM ACSR
174
0161 CLOVERDALE, VA
ROANOKE, VA
0
0
1
0
0
795KCM ACSR
175
0160 CLOVERDALE, VA
REUSENS, VA
138
138
36
8
1
397KCM ACSR
176
0160 CLOVERDALE, VA
REUSENS, VA
138
138
1
0
0
636 KCM ACSR
177
MOSELEY, VA
REUSENS, VA
138
138
0
22
1
397KCM ACSR
178
0163 MOSELEY, VA
ROANOKE, VA
138
138
1
20
1
795KCM ACSR
179
0421 MOUNT UNION
CLOVERDALE
138
138
7
0
1
795KCM ACSR
180
0292 VINTON LOOP, VA
138
138
0
0
1
795KCM ACSR
181
0396 BONSACK LOOP, VA
138
138
0
0
1
795KCM ACSR
182
0168 EAST DANVILLE, VA
SMITH MOUNTAIN, VA
138
138
32
0
1
556KCM ACSR
183
0168A BEARSKIN TAP, VA
138
138
0
0
1
556KCM ACSR
184
0419 PENHOOK, VA
SMITH MOUNTAIN, VA
138
138
7
0
1
1033KCM ACSR
185
0371 PENHOOK, VA
WESTLAKE
138
138
15
0
1
1033KCM ACSR
186
0371 PENHOOK, VA
WESTLAKE
138
138
0
0
2
1033KCM ACSR
187
0369 BLAINE, VA
WESTLAKE
138
138
11
0
1
1033.5 KCM ACSR
188
0423 STONEWALL TAP
69
138
8
0
1
189
0423 STONEWALL TAP
0
0
1
0
0
795 KCM ACSR
190
0259 REGIS, VA
MONUMENT, VA
138
138
2
1
1
795KCM ACSR
191
0266 HANCOCK, VA
ROANOKE ELECTRIC STEEL, VA
138
138
1
0
1
795KCM ACSR
192
0266 HANCOCK, VA
ROANOKE ELECTRIC STEEL, VA
0
0
0
0
0
193
0042 SALTVILLE, VA
TAZEWELL, VA
138
138
21
0
1
1272KCM ACSR
194
0042 SALTVILLE, VA
TAZEWELL, VA
138
138
0
21
1
397KCM ACSR
195
0042 SALTVILLE, VA
TAZEWELL, VA
138
138
0
0
1
1033KCM ACSR
196
0270 BLUEFIELD, WV
TAZEWELL, VA
138
138
20
0
1
795KCM ACSR
197
0270 BLUEFIELD, WV
TAZEWELL, VA
138
138
0
0
1
1033KCM ACSR
198
BAILEYSVILLE, WV
TAZEWELL, VA
138
138
9
0
1
397KCM ACSR
199
BAILEYSVILLE, WV
TAZEWELL, VA
138
138
0
9
1
397KCM ACSR
200
0338 BLUEFIELD, VA
SOUTH PRINCETON, VA
138
138
6
0
1
556KCM ACSR
201
0414 RIVERVILLE TAP, VA
138
138
0
0
1
795KCM ACSR
202
0132 ROANOKE
CAROLINA
138
138
9
0
0
203
0132 ROANOKE
CAROLINA
138
138
44
57
1
795KCM ACSR
204
0385 CAPITALIZED SPARE PART
MAX MEADOW
138
138
0
0
1
205
1004 KEYWOOD TAP
138
138
0
0
0
206
0467 CLEARBROOK, VA
MATT FUNK, VA
138
138
0
0
1
1590KCM ACSR
207
0380 FALLING BRANCH
MERRIMAC
138
138
6
0
1
1033 KCM ACSR
208
0380 FALLING BRANCH
MERRIMAC
138
138
1
0
1
1033 KCM ACSR
209
0380 FALLING BRANCH
MERRIMAC
69
138
1
0
1
1033 KCM ACSR
210
0381 LAKE FOREST, VA
138
138
3
0
2
1590KCM ACSR
211
0464 HUNTINGTON COURT
ROANOKE
138
138
6
0
1
795 ACSR
212
0464 HUNTINGTON COURT
ROANOKE
138
138
0
0
1
1590KCM ACSR
213
0465 SUNSCAPE
138
138
1
0
2
1590KCM ACSR
214
0470 LOCKHART, VA
138
138
0
0
1
795KCM ACSR
215
0435 DUTY, VA
138KV EXTENSION
138
138
0
0
1
216
0388 TECH DRIVE
138KV EXTENSION
138
138
0
0
1
1590 KCM ACSR
217
0484 HORSEPEN
138KV EXTENSION
138
138
0
0
0
218
0485 JACKSONS FERRY
WYTHE
138
138
5
0
1
1590KCM ACSR/MA2
219
0485 JACKSONS FERRY
WYTHE
138
138
13
0
2
1590KCM ACSR/MA2
220
0502 PROGRESS PARK TAP
138
138
1
0
1
1590KCM ACSR/MA2
221
0502 PROGRESS PARK TAP
138
138
0
0
1
1590KCM ACSR/MA2
222
0512 CLOVERDALE 765
CLOVERDALE 138
345
345
0
0
1
1590KCM ACSS
223
0508 CLOVERDALE EAST
CLOVERDALE TIE LINE NO 2
345
345
0
0
1
2-1926.9KCM ACSR/
224
0509 CLOVERDALE 765
CLOVERDALE EAST
500
500
0
0
1
4-954KCM ACSR
225
0516 RICHLANDS
WHITEWOOD
138
138
8
0
1
1033.5KCM ACSR
226
0513 WHITEWOOD EXT
138
138
1
0
2
1033.5KCM ACSR
227
0513 WHITEWOOD EXT
138
138
0
0
2
1033.5KCM ACSR
228
0519 OWENS DRIVE EXT
69
138
2
0
1
795KCM ACSR
229
0459 GEORGE STREET
LYNBROOK
138
138
1
0
1
1233.6KCM ACSR/TW
230
0459 GEORGE STREET
LYNBROOK
138
138
2
0
1
1233.6KCM ACSR/TW
231
0110A FALLING BRANCH
LOOP
138
138
1
0
1
556.5 KCM 26/7 AC
232
0460 BRUSH TAVERN
LYNBROOK
138
138
4
0
1
1233.6KCM ACSR/TW
233
0501 JACKSONS FERRY
BUS TIE #3
138
138
0
0
1
1590 KCM ACSR
234
0461 George Street
South Lynchburg
138
138
3
0
1
1233.6KCM ACSR/TW
235
0461 George Street
South Lynchburg
138
138
0
0
1
1233.6KCM ACSR/TW
236
0507 Cloverdale East
Cloverdale Tie Line No. 1
345
345
0
0
1
2 - 1926.9 KCM AC
237
0517 Town Creek
Progress Park
138
138
3
0
1
1033.5KCM ACSR
238
0517 Town Creek
Progress Park
138
138
7
0
1
1033.5KCM ACSR
239
0517 Town Creek
Progress Park
138
138
3
0
1
1033.5KCM ACSR
240
0518 TOWN CREEK
SOUTH BLUEFIELD
138
138
1
0
1
1033.5KCM ACSR
241
0518 TOWN CREEK
SOUTH BLUEFIELD
138
138
1
0
1
1033.5KCM ACSR
242
0518 TOWN CREEK
SOUTH BLUEFIELD
138
138
10
0
1
1033.5KCM ACSR
243
0514 BEARWALLOW
FARADAY
138
138
2
0
1
1033.5KCM ACSR
244
0515 FARADAY
TAZEWELL
138
138
7
0
1
1033.5KCM ACSR
245
0545 Tazewell Bus Tie No 1
138
138
0
0
1
1033.5KCM ACSR
246
0569 HINTON
WEST VACO (VA)
138
138
0
0
1
336KCM ACSR
247
0522 SOUTH ABINGDON EXT
138
138
4
0
2
1033.5KCM ACSR
248
0524 Joshua Falls 765/138kV Bus Tie No. 1
138
138
0
0
1
1590KCM ACSR
249
0541 IRONTO EXTENSION
138
138
0
0
2
1033.5KCM ACSR
250
0537 WOLF GLADE EXTENSION
138
138
2
0
2
795KCM ACSR
251
0567 Glenmary Extension
138
138
0
0
2
795KCM ACSR
252
0581 Museville Extension
138
138
0
0
2
1272 ACSS
253
0538 Elk Garden Tap
138
138
0
0
1
1590KCM ACSR
254
0538 Elk Garden Tap
138
138
0
0
1
336KCM ACSR
255
0571 Garden Creek
Baileysville (VA)
138
138
13
0
1
636KCM ACSR
256
0578 Redeye Extension
138
138
0
0
2
795KCM ACSR
257
STATE OF WEST VIRGINIA
STATE OF WEST VIRGINIA
0
0
258
0276 AMOS, WV
HANGING ROCK, H
765
765
25
0
1
954KCM ACSR
259
0297 GAVIN, OH
MOUNTAINEER, WV
765
765
8
0
1
1351KCM ACSR
260
0296 KAMMER, WV
MOUNTAINEER, WV
765
765
19
0
1
1351KCM ACSR
261
0296 KAMMER, WV
MOUNTAINEER, WV
0
0
95
0
0
262
0183 AMOS, WV
CULLODEN, WV
765
765
15
0
1
954KCM ACSR
263
0183A BAKER, KY
CULLODEN, WV
765
765
34
0
1
954KCM ACSR
264
0324 CULLODEN, WV
WYOMING, WV
765
765
58
0
1
1351KCM ACSR
265
0344 CULLODEN, WV
GAVIN, OH
765
765
42
0
1
1351KCM ACSR
266
0405 JACKSONS FERRY
WYOMING
765
765
32
0
1
795KCM ACSR
267
0295 AMOS, WV
MOUNTAINEER, WV
765
765
47
0
1
1351KCM ACSR
268
0185 BAKER, KY
BROADFORD, VA
765
765
4
0
1
954KCM ACSR
269
0263 AMOS, WV
GAVIN
765
765
0
0
1
270
0012 BAKER, KY
TRI STATE, WV
345
345
6
0
1
954KCM ACSR
271
0003 KYGER CREEK, OH
SPORN, WV
345
345
12
0
1
1414KCM ACSR
272
0003 KYGER CREEK, OH
SPORN, WV
345
345
0
0
1
1272 ACSS
273
0004 MUSKINGUM, WV
SPORN, WV
345
345
0
2
1
1275KCM ACSR
274
0004 MUSKINGUM, WV
SPORN, WV
345
345
2
0
2
959.6 KCM ACSS
275
0005 KANAWHA, WV
MATT FUNK, VA
345
345
1
0
1
2156KCM ACSR
276
0005 KANAWHA, WV
MATT FUNK, VA
345
345
64
0
1
2-954KCM ACSR
277
0218 AMOS, WV
SPORN, WV
345
345
46
0
1
1563KCM ACSR
278
0006 KANAWHA, WV
SPORN, WV
345
345
0
62
1
1414KCM ACSR
279
0006A AMOS, WV
KANAWHA, WV
345
345
28
12
1
1563KCM ACSR
280
0011 KYGER CREEK, WV
TRI-STATE, WV
345
345
63
0
0
2303KCM ACSR
281
0011 KYGER CREEK, WV
TRI-STATE, WV
345
345
0
0
0
2303KCM ACSR
282
0228A BETH TAP WV
138
138
1
0
1
336KCM ACSR
283
0053 BAILEYSVILLE, WV
HALES BRANCH, VA
138
138
0
0
2
636KCM ACSR
284
0308 PAD FORK LOOP, WV
138
138
0
0
1
397KCM ACSR
285
0330 JIM BRANCH, WV
WYOMING, WV
138
138
7
0
1
1590KCM ACSR
286
0330 JIM BRANCH, WV
WYOMING, WV
0
0
16
0
0
287
0210 BAILYESVILLE, WV
WYOMING, WV
138
138
0
5
1
1590KCM ACSR
288
0332 WELCH TAP, WV
138
138
0
0
1
795KCM ACSR
289
0053 BAILEYSVILLE, WV
HALES BRANCH, VA
138
138
21
0
1
636KCM ACSR
290
0035 STOTESBURY TAP, WV
138
138
0
0
1
795KCM ACSR
291
0035 STOTESBURY TAP, WV
138
138
6
0
1
795KCM ACSR
292
0211 MULLENSVILLE LOOP, WV
138
138
1
1
1
556KCM ACSR
293
0212 PINNACLE CREEK LOOP, W
138
138
3
3
1
556KCM ACSR
294
0294 NORTH BECKLEY LOOP, WV
138
138
1
1
1
556KCM ACSR
295
0210 BAILEYSVILLE, WV
WYOMING, WV
138
138
0
6
1
1590KCM ACSR
296
MULLENS, WV
WYOMING, WV
138
138
6
0
1
556KCM ACSR
297
MULLENS, WV
WYOMING, WV
0
0
17
0
0
298
0356 PEMBERTON TAP, WV
138
138
0
0
1
336KCM ACSR
299
0356 PEMBERTON TAP, WV
138
138
1
0
1
336KCM ACSR
300
0356 PEMBERTON TAP, WV
138
138
1
0
1
336KCM ACSR
301
0216B BRADLEY, WV
TAMS MOUNTAIN, WV
138
138
1
0
1
556KCM ACSR
302
0216B BRADLEY, WV
TAMS MOUNTAIN, WV
138
138
14
0
1
556KCM ACSR
303
0216B BRADLEY, WV
TAMS MOUNTAIN, WV
138
138
1
0
1
556KCM ACSR
304
0216 MULLENS, WV
TAMS MOUNTAIN, WV
138
138
9
0
1
556KCM ACSR
305
0216 MULLENS, WV
TAMS MOUNTAIN, WV
138
138
0
0
0
556KCM ACSR
306
0094 BIG SANDY, KY
DEWEY, KY
138
138
0
0
1
636KCM ACSR
307
0426 BIG SANDY, KY
INEZ A&B, KY
138
138
8
0
1
795KCM ACSR
308
0092 BELLEFONTE, KY
TRI STATE, WV
138
138
4
0
1
795KCM ACSR
309
0429 MIDKIFF, WV
TRI STATE, WV
138
138
26
0
1
795KCM ACSR
310
0028 CABIN CREEK, WV
KANAWHA #1, WV
138
138
0
3
1
556KICM ACSR
311
0029 CABIN CREEK, WV
KANAWHA #2, WV
138
138
3
0
1
556KCM ACSR
312
0098 CAPITOL HILL, WV
KANAWHA, WV
138
138
18
0
1
556KCM ACSR
313
0098 CAPITOL HILL, WV
KANAWHA, WV
138
138
3
0
1
556KCM ACSS
314
0326 RENSFORD LOOP, WV
KANAWHA, WV
138
138
1
0
1
556KCM ACSR
315
0098A FLATWOOD TAP, WV
138
138
5
0
1
795KCM ACSR
316
0245 GILBOA, WV
KANAWHA, WV
138
138
0
0
1
795KCM ACSR
317
0245 GILBOA, WV
KANAWHA, WV
0
0
15
0
0
318
0390 BELVA TAP, WV
138
138
1
1
1
954KCM ACSR
319
0372 JEHU EXT WV
138
138
1
0
1
556KCM ACSR
320
0097 CAPITOL HILL, WV
CHEMICAL, WV
138
138
6
0
2
556KCM ACSR
321
0097 CAPITOL HILL, WV
CHEMICAL, WV
138
138
0
0
1
1272KCM ACSS
322
0101 DEXTER, WV
SPORN CIR B, OH
138
138
9
0
1
397KCM ACSR
323
0101 DEXTER, WV
SPORN CIR B, OH
138
138
0
0
1
397KCM ACSR
324
0104 BANCROFT TAP, WV
138
138
1
0
1
556KCM ACSR
325
0101 DEXTER, OH
SPORN CIR A, WV
138
138
0
9
1
397KCM ACSR
326
0225A LEON LOOP, WV
138
138
0
0
1
1033KCM ACSR
327
AMERICAN ALLOYS, WV
SPORN, WV
138
138
0
0
1
556KCM ACSR
328
0402 SISSON TAP, WV
138
138
10
1
1
795KCM ACSR
329
0402 SISSON TAP, WV
0
0
0
0
0
330
0225 AMOS, WV
SOUTH BUFFALO CIR B, WV
138
138
12
6
1
397KCM ACSR
331
0225 SOUTH BUFFALO, WV
SPORN CIR A, WV
138
138
0
31
1
397KCM ACSR
332
0225 SOUTH BUFFALO, WV
SPORN CIR B WV
138
138
36
0
1
1351KCM ACSR
333
0023 MINNIX MOUNTAIN LOOP
138
138
0
0
1
1033KCM ACSR
334
0024 SPEEDWAY TAP, WV
138
138
0
0
1
556KCM ACSR
335
0024 SPEEDWAY TAP, WV
0
0
7
0
0
336
0020 GLEN LYN, VA
SOUTH PRINCETON, WV
138
138
13
0
1
397KCM ACSR
337
0424 GLEN LYN, VA
SOUTH PRINCETON, WV
138
138
0
13
1
1351KCM ACSR
338
0020A SOUTH PRINCETON, WV
SWITCHBACK A, WV
138
138
15
0
1
397KCM ACSR
339
0020B SOUTH PRINCETON, WV
SWITCHBACK B, WV
138
138
0
15
1
397KCM ACSR
340
0055 GLEN LYN, VA
WYTHE, VA
138
138
1
0
1
556KCM ACSR
341
0055 GLEN LYN, VA
WYTHE, VA
138
138
0
1
1
556KCM ACSR
342
0093 BIG SANDY
WEST HUNTINGTON, WV
138
138
0
0
2
1780KCM ACSR
343
0093 BIG SANDY
WEST HUNTINGTON, WV
138
138
3
0
1
1351KCM ACSR
344
0093 BIG SANDY
WEST HUNGINGTON, WV
0
0
16
0
0
345
0031 BRADLEY, WV
KANAWHA #1, WV
138
138
0
27
1
556KCM ACSR
346
0222 BRADLEY, WV
KANAWHA #2, WV
138
138
27
0
1
556KCM ACSR
347
0032 BRADLEY CIR A, WV
GLEN LYN-HINTON, VA
138
138
0
41
1
556KCM ACSR
348
0223 BRADLEY CIR B, WV
GLEN LYN-HINTON, VA
138
138
43
2
1
1590KCM ACSR
349
0219 KINCAID LOOP, WV
138
138
0
0
1
556KCM ACSR
350
0246 BRADLEY, WV
DAMERON, WV
138
138
10
0
1
795KCM ACSR
351
0415 CLIFFTOP TAP, WV
138
138
3
0
1
795KCM ACSR
352
0049 BAILEYSVILLE, WV
KANAWHA #1, WV
138
138
46
0
1
636KCM ACSR
353
0049 BAILEYSVILLE, WV
KANAWHA #2, WV
138
138
0
46
1
636KCM ACSR
354
0049 BAILEYSVILLE, WV
KANAWHA #2, WV
0
0
0
0
0
355
0052 BIM TAP, WV
138
138
12
0
1
556KCM ACSR
356
3827 BRADLEY
LAYLAND
69
138
12
0
1
357
3484 COBB TAP
46
138
0
0
1
358
0420 FRANKS BRANCH
46
138
5
0
1
359
2123 SOUTH NEAL
WEST HUNTINGTON
69
138
2
0
1
360
0220 KOPPERSTON LOOP, WV
138
138
0
0
1
1033KCM ACSR
361
0243 BOLT TAP, WV
138
138
6
0
1
795KCM ACSR
362
0301 WHARTON TAP, WV
138
138
0
0
1
556KCM ACSR
363
0384 HINTON
WESTVACO, WV
138
138
13
0
1
556KCM ACSR
364
0384 HINTON
WESTVACO, WV
138
138
23
0
1
336KCM ACSR
365
0389 GREENBRIER LOOP, WV
138
138
0
0
1
246KCM ACAR
366
0393 RONCEVERTE LOOP, WV
138
138
0
0
1
4/0 ACSR
367
0357 GRASSY FALLS, WV
MCCLUNG, WV
138
138
0
0
1
954KCM ACSR
368
0304 RUM CREEK TAP, WV
138
138
2
0
1
556KCM ACSR
369
0318 M&B TAP, WV
138
138
0
0
1
556KCM ACSR
370
0013 LOGAN, WV
WYOMING #1-A, WV
138
138
12
14
1
1590KCM ACSR
371
0013 LOGAN, WV
WYOMING #1-B, WV
138
138
22
0
1
1590KCM ACSR
372
0387 LOGAN, WV
WYOMING #2, WV
138
138
23
0
1
1033KCM ACSR
373
0387 LOGAN, WV
WYOMING #2, WV
138
138
0
0
1
1033KCM ACSR
374
0045 LOGAN, WV
SPRIGG #1 & #2, WV
138
138
18
0
2
397KCM ACSR
375
3791 BOLT, WV
TRAP HILL, WV
46
138
6
0
1
376
0048 CHAUNCEY TAP, WV
138
138
4
0
1
397KCM ACSR
377
0328 RAGLAND LOOP, WV
138
138
1
0
1
556KCM ACSR
378
0317 GRANT BRANCH TAP, WV
138
138
7
0
1
556KCM ACSR
379
0346 PINE CREEK TAP, WV
138
138
2
0
1
556KCM ACSR
380
0401 HATFIELD, WV
SPRIGG, WV
138
138
11
0
1
1033KCM ACSR
381
0401A CINDERELLA LOOP, WV
138
138
0
0
1
1035KCM ACSR
382
0325 JIM BRANCH, WV
SWITCHBACK, WV
138
138
18
1
1
1033KCM ACSR
383
0077 MILLBROOK, OH
SPORN, WV
138
138
9
0
1
477KCM ACSR
384
0077A ADDISON LICK, WV
SPORN, WV
138
138
0
9
1
477KCM ACSR
385
0075 SOUTH POINT, OH
SPORN, WV
138
138
10
0
1
397KCM ACSR
386
0075 SOUTH POINT, OH
SPORN, WV
138
138
1
0
1
397KCM ACSR
387
NORTH PROCTORVILLE, OH
SPORN, WV
138
138
0
10
1
397KCM ACSR
388
0076 DARRAH, WV
NORTH PROCTORVILLE, OH
138
138
2
0
1
795KCM ACSR
389
0076 DARRAH, WV
NORTH PROCTORVILLE, OH
138
138
0
2
1
556KCM ACSR
390
0081 RAVENSWOOD, WV
SPORN #1, WV
138
138
1
0
1
795KCM ACSR
391
0081 RAVENSWOOD, WV
SPORN #2, WV
138
138
0
1
1
795KCM ACSR
392
0083 RAVENSWOOD, WV
SPORN #3, WV
138
138
1
0
1
795KCM ACSR
393
0083 RAVENSWOOD, WV
SPORN #4, WV
138
138
0
1
1
795KCM ACSR
394
0247 EAST HUNTINGTON, WV
NORTH PROCTORVILLE, OH
138
138
1
0
1
795KCMACSR
395
0067 JOHNS CREEK, KY
SPRIGG, WV
138
138
1
0
1
397KCM ACSR
396
0271 BLUEFIELD, WV
TAZEWELL, VA
138
138
1
0
1
795KCM ACSR
397
0017 BAILEYSVILLE, WV
TAZEWELL, VA
138
138
31
0
1
1590KCM ACSR
398
0016 BAILEYSVILLE, WV
TAZEWELL,  VA
138
138
3
28
1
397KCM ACSR
399
0016A CARSWELL TAP, WV
138
138
1
1
1
397KCM ACSR
400
0069 CABIN CREEK, WV
TURNER #1 CIR A, WV
138
138
23
0
1
336KCM ACSR
401
0070 CABIN CREEK, WV
TURNER #1 CIR B. WV
138
138
5
19
1
1590KCM ACSR/MA
402
0194 CHESTERFIELD TAP, WV
138
138
0
0
0
403
0071 CABIN CREEK, WV
TURNER #2, WV
138
138
0
1
1
250KCM ACSR
404
0071 CABIN CREEK, WV
TURNER #2, WV
0
0
22
0
0
405
0268 ST ALBANS LOOP, WV
138
138
0
0
1
1033KCM ACSR
406
0230 AMOS, WV
TURNER #1, WV
138
138
12
0
1
1033KCM ACSR
407
0230 AMOS, WV
TURNER #2, WV
138
138
0
12
1
1033KCM ACSR
408
0226 AMOS, WV
CHEMICAL #1 A, WV
138
138
1
8
1
397KCM ACSR
409
0226 AMOS, WV
CHEMICAL #1 B, WV
138
138
6
0
1
1033KCM ACSR
410
0226 AMOS, WV
CHEMICAL #2 A, WV
138
138
8
9
1
1033KCM ACSR
411
0226 AMOS, WV
CHEMICAL #2 B, WV
138
138
0
4
1
397KCM ACSR
412
0226 AMOS, WV
CHEMICAL 1A-2A AND 1B-2B
138
138
1
0
2
1033 KCM ACSR
413
0343 STONE BRANCH TAP, WV
138
138
6
0
1
795KCM ACSR
414
HOPKINS, WV
LOGAN, WV
138
138
8
11
1
336KCM ACSR
415
HOPKINS, WV
LOGAN, WV
138
138
19
0
1
336KCM ACSR
416
0228 AMOS, WV
HOPKINS, WV
138
138
2
17
1
336KCM ACSR
417
0228 AMOS, WV
HOPKINS, WV
138
138
28
0
1
795KCM ACSR
418
0228 AMOS, WV
HOPKINS, WV
138
138
2
0
1
1590KCM ACSR/MA
419
0364 GRASSY FORK TAP, WV
138
138
2
0
1
795KCM ACSR
420
0376 DINGESS LOOP, WV
138
138
0
0
1
1033KCM ACSR
421
0376 DINGESS LOOP, WV
0
0
0
0
0
422
0306 INEZ, KY
LOGAN, WV
138
138
0
1
1
795KCM ACSR
423
0306 INEZ, KY
LOGAN, WV
0
0
23
0
0
424
0428 SHARPLES TAP 138KV
138
138
7
0
1
795KCM ACSR
425
0432 MUD FORK LOOP, WV
138
138
1
1
1
795KCM ACSR
426
0087 DARRAH, WV
TRI STATE, WV
138
138
10
4
1
397KCM
427
0436 DAWES LOOP, 138KV, WV
138
138
0
0
0
428
0088 TRI-STATE, WV
WEST HUNTINGTON, WV
138
138
0
6
1
397KCM ACSR
429
0090 SOUTH POINT, OH
TRI-STATE CIR A, WV
138
138
8
0
1
397KCM ACSR
430
0090 SOUTH POINT, OH
TRI-STATE CIR B, WV
138
138
0
7
1
1351KCM ACSR
431
0225 AMOS
SPORN
138
138
0
11
0
397KCM ACSR
432
0237 AMOS, WV
DARRAH, WV
138
138
35
0
1
397KCM ACSR
433
0238 AMOS, WV
WEST HUNTINGTON, WV
138
138
5
41
1
1033KCM ACSR
434
0238 AMOS, WV
WEST HUNTINGTON, WV
0
0
0
0
0
435
0238 PARK HILL TAP, WV
138
138
0
0
1
397KCM ACSR
436
0277 CABELL LOOP, WV
138
138
1
1
1
954KCM ACSR
437
0302 MILTON LOOP, WV
138
138
2
2
1
795KCM ACSR
438
0378 CURRY LOOP, WV
138
138
2
2
1
1033KCM ACSR
439
0095 CARBIDE MAIN, WV
TURNER, WV
138
138
0
0
1
1590 KCM ACSR
440
0096 CARBIDE #8, WV
CHEMICAL-TURNER A, WV
138
138
0
1
1
397KCM ACSR
441
0096 CARBIDE #8, WV
CHEMICAL-TURNER B, WV
138
138
7
0
1
1033KCM ACSR
442
0096 CARBIDE #8, WV
CHEMICAL-TURNER B, WV
138
138
1
0
2
1033KCM ACSR
443
0337 BLUEFIELD, WV
SOUTH PRINCETON, WV
138
138
8
0
1
556KCM ACSR
444
0337 BLUEFIELD, WV
SOUTH PRINCETON, WV
138
138
0
0
2
556KCM ACSR
445
0336 CLENDENIN TAP
138
138
8
0
0
446
CAPITALIZED SPARE PARTS
0373,0379
138
138
0
0
1
447
1005 CHERRY CREEK
CLIFFTOP
138
138
7
0
1
795 ACSR
448
0377 SPORN
CLINE ENERGY EXTENSION
138
138
0
0
1
397KCM ACSR
449
0370 SOUTHRIDGE EXTENSION
138
138
2
0
2
1590KCM ACSR/MA
450
0098A FLATWOOD TAP 138KV
0
0
0
0
0
451
0386 GARRISON WV
138
138
0
0
2
795 KCM ACSR
452
0382 LANHAM, WV
138
138
1
0
2
795 KCM ACSR
453
0473 CARETTA
JIM BRANCH
138
138
0
0
0
454
0471 HALLS RIDGE
SOUTH PRINCETON, WV
138
138
0
0
1
1590KCM ACSR
455
0466 IAEGER
WHARNCLIFFE, WV
46
138
6
0
1
556.5KCM26/7 AC
456
1050 ROCKHOUSE
138
138
0
0
0
457
1072 CLENDENIN, WV
MORRIS BRANCH
138
138
2
0
1
795 KCM ACSR
458
0474 COBB, WV
THOROFARE CREEK
138
138
0
0
1
795 KCM ACSR
459
0463 CROOKED CREEK, WV
138
138
1
0
1
1033KCM ACSR
460
0472 MERRITS CREEK, WV
138
138
4
0
1
1033KCM ACSR
461
3843 BIM, WV
47
138
0
0
1
462
3843 BIM, WV
0
0
11
0
0
463
0478 POLYMER LOOP, WV
138
138
3
0
1
795 KCM ACSR
464
0478 POLYMER LOOP, WV
138
138
0
0
1
795KCM ACSR
465
0477 BROAD RUN, WV
THOROFARE CREEK
138
138
1
0
1
466
0475 PATRIOT COAL, WV
POINT LICK
138
138
0
0
1
556.5 KCM 26/7 AC
467
0482 CLARK BRANCH, WV
138KV EXTENSION
138
138
0
0
1
468
0481 LAKEVIEW
138KV EXTENSION
138
138
0
0
0
469
0483 HERNSHAW
138KV EXTENSION
138
138
2
0
2
1590 KCM ACSR
470
0486 PAX BRANCH
138KV EXTENSION
138
138
1
0
2
1033.5 KCM ACSR
471
0487 PIERPONT
138KV EXTENSION
138
138
1
0
1
1033.5 KCM
472
0479 HARMON BRANCH
138KV EXTENSION
138
138
1
0
2
1033.5 KCM ACSR
473
0492 TRI-STATE
TWELVEPOLE CREEK
138
138
1
0
2
795 KCM ACSR
474
0503 CLINTWOOD EXTENSION
69
138
0
0
2
1033.5 KCM ACSR
475
3827 BRADLEY
LAYLAND NO.2B
69
138
1
0
1
1158.4KCM ACSR/TW
476
0015 BERWIND
FARADAY
138
138
0
0
0
477
0018 BERWIND
YUKON
138
138
0
0
0
478
0016 JIM BRANCH
YUKON
138
138
0
0
0
479
0568 GRANGSTON LOOP
138
138
0
0
2
556.5KCM ACSR
480
0526 COMMONWEALTH CROSSING
138KV EXTENSION
138
138
6
0
2
1033 KCM ACSR
481
0527 COCO Extension
138
138
0
0
2
1033.5 KCM ACSR
482
0528 CAPITOL HILL
CHESTERFIELD AVE
69
138
0
0
1
1033.5 KCM ACSR
483
0539 TRI-STATE 345KV - 138KV BUS TIE NO. 1
138
138
0
0
1
2-1590KCM ACSR
484
0
0
485
Lines Under 138KV
1,568
181
486
Line cost and expense are
not available by individual
207,737,217
1,823,460,928
2,031,198,146
216,817
23,654,649
23,871,466
487
transmission line
Total shown in Column j - p
36 TOTAL
5,098
1,330
462
207,737,217
1,823,460,928
2,031,198,146
216,817
23,654,649
0
23,871,466


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
TRANSMISSION LINES ADDED DURING YEAR
  1. Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines.
  2. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m).
  3. If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.
LINE DESIGNATION SUPPORTING STRUCTURE CIRCUITS PER STRUCTURE CONDUCTORS LINE COST
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
LengthOfTransmissionLineAdded
Line Length in Miles
SupportingStructureOfTransmissionLineType
Type
AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles
Average Number per Miles
NumberOfTransmissionCircuitsPerStructurePresent
Present
NumberOfTransmissionCircuitsPerStructureUltimate
Ultimate
ConductorSize
Size
ConductorSpecification
Specification
ConductorConfigurationAndSpacing
Configuration and Spacing
OperatingVoltageOfTransmissionLine
Voltage KV (Operating)
CostOfLandAndLandRightsTransmissionLinesAdded
Land and Land Rights
CostOfPolesTowersAndFixturesTransmissionLinesAdded
Poles, Towers and Fixtures
CostOfConductorsAndDevicesTransmissionLinesAdded
Conductors and Devices
Asset Retire. Costs
CostOfTransmissionLinesAdded
Total
SupportingStructureConstructionType
Construction
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
(q)
1
0567 Glenmary Extension
0
3
2
2
138
1,705,103
190,164
1,895,267
2
0524 Joshua Falls 765/138kV Bus Tie No. 1
0
1
1
1
138
687,396
85,307
772,703
3
0581 Museville Extension
0
1
2
2
138
4,125
97,775
14,020
115,920
4
0578 Redeye Extension
0
1
2
2
138
77,341
77,341
5
0539 Tri State 345kV
138kV Bus Tie No. 1
0
3
1
1
138
34,203
22,802
57,005
6
0538 Elk Garden Tap
0
1
1
1
138
7
0538 Elk Garden Tap
0
2
1
1
138
371,735
116,070
487,805
44
TOTAL
1
12
10
10
4,125
2,973,554
428,363
3,406,041


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
SUBSTATIONS
  1. Report below the information called for concerning substations of the respondent as of the end of the year.
  2. Substations which serve only one industrial or street railway customer should not be listed below.
  3. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown.
  4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f).
  5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
  6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
Character of Substation VOLTAGE (In MVa) Conversion Apparatus and Special Equipment
Line No.
SubstationNameAndLocation
Name and Location of Substation
(a)
SubstationCharacterDescription
Transmission or Distribution
(b)
SubstationCharacterAttendedOrUnattended
Attended or Unattended
(b-1)
PrimaryVoltageLevel
Primary Voltage (In MVa)
(c)
SecondaryVoltageLevel
Secondary Voltage (In MVa)
(d)
TertiaryVoltageLevel
Tertiary Voltage (In MVa)
(e)
SubstationInServiceCapacity
Capacity of Substation (In Service) (In MVa)
(f)
NumberOfTransformersInService
Number of Transformers In Service
(g)
Number of Spare Transformers
(h)
ConversionApparatusAndSpecialEquipmentType
Type of Equipment
(i)
NumberOfConversionApparatusAndSpecialEquipmentUnits
Number of Units
(j)
CapacityOfConversionApparatusAndSpecialEquipment
Total Capacity (In MVa)
(k)
1
ABERT - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
9.60
2
ABERT - VA
Distribution
69.00
12.00
22.40
1
0
0.00
3
ABINGDON - VA
Transmission
138.00
13.09
22.40
1
0
0.00
4
ABINGDON - VA
Transmission
138.00
70.50
13.09
90.00
1
0
0.00
5
ABINGDON - VA
Transmission
138.00
34.50
50.00
2
0
0.00
6
ACCOVILLE - WV
Distribution
69.00
46.00
1.60
7.50
1
0
0.00
7
ALLOY - WV
Distribution
46.00
13.09
9.38
1
0
0.00
8
ALUM CREEK - WV
Distribution
46.00
13.09
9.38
1
0
0.00
9
ALUM RIDGE - VA
Distribution
138.00
33.00
12.00
9.38
1
0
0.00
10
AMBLER RIDGE - WV
Distribution
138.00
138.00
34.50
36.00
3
0
0.00
11
AMBLER RIDGE - WV
Distribution
138.00
36.20
34.50
72.00
6
0
0.00
12
AMEAGLE - WV
Distribution
46.00
7.20
2.49
3
0
0.00
13
AMHERST - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
9.60
14
AMHERST - VA
Distribution
69.00
13.09
25.00
1
0
0.00
15
AMONATE LIGHTS - WV
Distribution
34.50
7.20
0.75
3
0
0.00
16
AMOS 345KV - WV
Transmission
345.00
138.00
34.50
1350.00
2
0
0.00
17
AMOS 765KV - WV
Transmission
765.00
138.00
13.80
750.00
3
0
0.00
18
AMOS 765KV - WV
Transmission
138.00
69.00
46.00
130.00
0
1
0
0.00
19
AMOS 765KV - WV
Transmission
765.00
345.00
34.50
0
1
0
0.00
20
AMOS 765KV - WV
Transmission
765.00
345.00
34.50
1500.00
3
0
0.00
21
APPLE GROVE - WV
Transmission
69.00
12.00
10.50
1
0
0.00
22
APPLE GROVE - WV
Transmission
138.00
69.00
12.00
56.00
1
0
0.00
23
ARCHER CREEK - VA
Distribution
69.00
12.00
10.50
1
0
0.00
24
ARROWHEAD - VA
Distribution
69.00
13.09
12.00
1
0
0.00
25
ATKINS - VA
Distribution
138.00
34.50
12.00
9.38
0
1
0
0.00
26
ATKINS - VA
Distribution
69.00
12.00
10.50
0
1
0
0.00
27
ATKINS - VA
Distribution
138.00
34.50
30.00
1
0
0.00
28
AUSTINVILLE - VA
Distribution
138.00
34.50
1
0
0.00
29
AXTON - VA
Transmission
765.00
138.00
13.80
750.00
3
0
0.00
30
AXTON - VA
Transmission
765.00
REACTOR
4
400.00
31
AXTON - VA
Transmission
138.00
0.00
0.00
0.00
AIR CORE REACTOR
3
32
BAILEYSVILLE - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
33
BAILEYSVILLE - WV
Transmission
138.00
0.00
0.00
0.00
STATCAP
2
126.00
34
BAILEYSVILLE - WV
Transmission
138.00
46.00
90.00
1
0
0.00
35
BAILEYSVILLE - WV
Transmission
46.00
12.00
6.25
1
0
0.00
36
BALD KNOB - WV
Distribution
46.00
12.00
2.50
1
0
0.00
37
BALLOU - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
2
32.40
38
BANCROFT - WV
Transmission
138.00
13.09
25.00
1
0
0.00
39
BANCROFT - WV
Transmission
0.00
0.00
0.00
STATCAP
1
40
BANCROFT - WV
Transmission
138.00
69.00
12.00
67.20
1
0
0.00
41
BANCROFT - WV
Transmission
138.00
34.50
20.00
1
0
0.00
42
BARNETT - WV
Distribution
69.00
13.09
20.00
1
0
0.00
43
BARNETT - WV
Distribution
69.00
12.00
20.00
1
0
0.00
44
BASSETT - VA
Distribution
69.00
12.00
25.00
1
0
0.00
45
BASSETT WALKER - VA
Distribution
34.50
7.20
5.64
3
0
0.00
46
BASSETT WALKER - VA
Distribution
34.50
7.50
3.75
3
0
0.00
47
BEALE - WV
Distribution
69.00
13.09
7.50
1
0
0.00
48
BEARWALLOW - VA
Transmission
138.00
70.50
13.09
54.00
1
0
0.00
49
BECCO - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
9.60
50
BECCO - WV
Distribution
46.00
12.00
9.38
1
0
0.00
51
BECKLEY - WV
Distribution
46.00
4.16
6.25
1
0
0.00
52
BECKLEY - WV
Distribution
46.00
12.00
40.00
2
0
0.00
53
BECKLEY - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
12.00
54
BELCHER MOUNTAIN - WV
Distribution
88.00
14.00
4.50
3
0
0.00
55
BELLE - WV
Transmission
46.00
12.00
20.00
1
0
0.00
56
BELVA - WV
Transmission
138.00
46.00
30.00
1
0
0.00
57
BELVA - WV
Transmission
138.00
34.50
9.38
1
0
0.00
58
BENS CREEK - WV
Distribution
46.00
13.20
2.50
1
0
0.00
59
BENT MOUNTAIN - VA
Distribution
138.00
13.09
8.40
1
0
0.00
60
BENT MOUNTAIN - VA
Distribution
138.00
34.00
10.50
1
0
0.00
61
BIG BRANCH - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
62
BIG ROCK - VA
Distribution
34.50
13.65
5.00
1
0
0.00
63
BIM - WV
Transmission
138.00
69.00
46.00
84.00
1
0
0.00
64
BIM - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
14.40
65
BIM - WV
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
13.19
66
BLACKWATER - VA
Distribution
34.50
0.00
0.00
0.00
STATCAP
1
9.60
67
BLACKWATER - VA
Distribution
34.50
12.00
20.00
1
0
0.00
68
BLAINE - VA
Distribution
138.00
13.09
8.40
1
0
0.00
69
BLAINE - VA
Distribution
138.00
0.00
0.00
0.00
STATCAP
1
52.80
70
BLAINE - VA
Distribution
138.00
34.50
30.00
1
0
0.00
71
BLUE PENNANT - WV
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
14.40
72
BLUE RIDGE - VA
Distribution
12.00
4.00
0.30
3
0
0.00
73
BLUE RIDGE - VA
Distribution
34.50
12.00
10.94
2
0
0.00
74
BLUEFIELD AVENUE - WV
Distribution
138.00
13.09
44.80
2
0
0.00
75
BOLT - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
76
BOLT - WV
Transmission
138.00
69.00
46.00
129.00
1
0
0.00
77
BONSACK - VA
Distribution
138.00
34.50
30.00
1
0
0.00
78
BOONE - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
9.60
79
BOONE - WV
Distribution
46.00
12.00
4.69
1
0
0.00
80
BOONSBORO - VA
Distribution
138.00
13.09
20.00
1
0
0.00
81
BORDERLAND - WV
Distribution
138.00
13.09
20.00
1
0
0.00
82
BOWYER - WV
Distribution
46.00
7.20
3.00
3
0
0.00
83
BOXWOOD - VA
Distribution
138.00
13.09
20.00
1
0
0.00
84
BRADLEY - WV
Transmission
138.00
69.00
46.00
130.00
1
0
0.00
85
BRADLEY - WV
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
50.40
86
BRADLEY - WV
Transmission
46.00
12.00
8.40
1
0
0.00
87
BRIAR MOUNTAIN - WV
Distribution
46.00
7.20
3.00
3
0
0.00
88
BRIDGE - WV
Distribution
69.00
13.09
45.00
2
0
0.00
89
BROADFORD - VA
Transmission
765.00
138.00
13.80
3
0
0.00
90
BROADFORD - VA
Transmission
765.00
REACTOR
3
300.00
91
BROCKWAY GLASS - VA
Distribution
69.00
4.00
9.38
1
0
0.00
92
BROOKVILLE - VA
Distribution
138.00
13.09
22.40
1
0
0.00
93
BROWNSVILLE (AP) - WV
Distribution
69.00
12.00
6.25
1
0
0.00
94
BRUSH TAVERN - VA
Distribution
138.00
34.50
60.00
2
0
0.00
95
BUCKHORN - VA
Distribution
138.00
34.50
30.00
1
0
0.00
96
BURLINGTON HEIGHTS - VA
Distribution
138.00
34.50
30.00
1
0
0.00
97
BYLLESBY - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
13.19
98
CABELL - WV
Distribution
138.00
34.50
30.00
1
0
0.00
99
CABELL - WV
Distribution
138.00
36.20
30.00
1
0
0.00
100
CABIN CREEK 46KV - WV
Transmission
138.00
46.00
75.00
1
0
0.00
101
CABIN CREEK 46KV - WV
Transmission
46.00
12.00
22.40
1
0
0.00
102
CABIN CREEK 46KV - WV
Transmission
138.00
46.20
75.00
1
0
0.00
103
CAMBRIA - VA
Distribution
69.00
13.09
25.00
1
0
0.00
104
CAMPBELL AVENUE - VA
Distribution
34.50
0.00
0.00
0.00
STATCAP
1
9.60
105
CAMPBELL AVENUE - VA
Distribution
69.00
34.50
30.00
1
0
0.00
106
CAMPBELL AVENUE - VA
Distribution
69.00
12.00
44.80
2
0
0.00
107
CANDLERS MOUNTAIN - VA
Distribution
138.00
13.09
22.40
1
0
0.00
108
CAPITOL HILL 138KV - WV
Transmission
138.00
13.09
20.00
1
0
0.00
109
CAPITOL HILL 138KV - WV
Transmission
138.00
69.00
46.00
90.00
1
0
0.00
110
CAPITOL HILL 138KV - WV
Transmission
138.00
46.00
45.00
1
0
0.00
111
CAPITOL HILL 46KV - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
18.00
112
CARBONDALE - WV
Transmission
46.00
36.20
10.50
1
0
0.00
113
CARBONDALE - WV
Transmission
138.00
69.00
46.00
128.80
1
0
0.00
114
CARSWELL - WV
Transmission
138.00
88.00
7.98
60.00
3
0
0.00
115
CATAWBA - VA
Transmission
138.00
69.00
34.50
1
0
0.00
116
CATAWBA - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
16.20
117
CATAWBA - VA
Transmission
138.00
34.50
30.00
1
0
0.00
118
CATAWBA - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
64.80
119
CAVE SPRING - VA
Distribution
138.00
13.09
42.40
2
0
0.00
120
CEDAR GROVE (AP) - WV
Distribution
46.00
12.00
5.00
1
0
0.00
121
CENTERVILLE - VA
Transmission
138.00
69.00
34.50
84.00
1
0
0.00
122
CENTERVILLE - VA
Transmission
138.00
13.09
10.50
1
0
0.00
123
CENTRAL AVENUE (AP) - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
20.39
124
CENTRAL MACHINE SHOP - WV
Distribution
46.00
4.00
3.75
1
0
0.00
125
CEREDO - WV
Distribution
34.50
4.00
6.25
1
0
0.00
126
CHAUNCEY - WV
Transmission
46.00
12.00
10.50
1
0
0.00
127
CHAUNCEY - WV
Transmission
138.00
46.00
19.50
30.00
3
0
0.00
128
CHEMICAL - WV
Transmission
138.00
69.00
46.00
84.00
1
0
0.00
129
CHEMICAL - WV
Transmission
138.00
46.00
290.00
3
0
0.00
130
CHEMICAL - WV
Transmission
46.00
12.00
22.40
1
0
0.00
131
CHEMICAL - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
2
52.19
132
CHERRY CREEK - WV
Distribution
138.00
34.50
30.00
1
0
0.00
133
CHERRY CREEK - WV
Distribution
138.00
46.00
90.00
0
1
0
0.00
134
CHERRY CREEK - WV
Distribution
138.00
13.09
20.00
1
0
0.00
135
CHESTERFIELD AVENUE - WV
Transmission
138.00
13.09
40.00
2
0
0.00
136
CHESTERFIELD AVENUE - WV
Transmission
138.00
70.50
46.00
90.00
1
0
0.00
137
CINDERELLA - WV
Distribution
138.00
13.09
20.00
1
0
0.00
138
CLAREMONT - WV
Distribution
69.00
12.00
8.40
1
0
0.00
139
CLAYPOOL HILL - VA
Distribution
138.00
13.09
40.00
2
0
0.00
140
CLAYTOR HILLTOP - VA
Transmission
0.00
0.00
0.00
STATCAP
1
57.60
141
CLEARBROOK - VA
Distribution
138.00
13.09
42.40
2
0
0.00
142
CLENDENIN - WV
Transmission
46.00
34.50
20.90
25.00
1
0
0.00
143
CLENDENIN - WV
Transmission
138.00
46.00
125.00
1
0
0.00
144
CLIFFORD - VA
Transmission
138.00
46.00
20.00
1
0
0.00
145
CLIFFORD - VA
Transmission
138.00
69.00
46.00
50.00
1
0
0.00
146
CLIFFORD - VA
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
3.59
147
CLIFFTOP - WV
Distribution
138.00
13.09
20.00
1
0
0.00
148
CLINCHFIELD - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
14.39
149
CLINCHFIELD - VA
Transmission
138.00
70.50
36.20
90.00
1
0
0.00
150
CLINTWOOD - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
9.60
151
CLINTWOOD - VA
Distribution
69.00
12.00
20.00
1
0
0.00
152
CLOVERDALE 138KV - VA
Transmission
345.00
137.50
13.14
448.00
1
0
0.00
153
CLOVERDALE 138KV - VA
Transmission
69.00
13.09
20.00
1
0
0.00
154
CLOVERDALE 138KV - VA
Transmission
138.00
70.50
36.20
200.00
0
1
0
0.00
155
CLOVERDALE 138KV - VA
Transmission
345.00
138.00
34.50
675.00
1
0
0.00
156
CLOVERDALE 138KV - VA
Transmission
345.00
137.50
13.80
450.00
1
0
0.00
157
CLOVERDALE 138KV - VA
Transmission
138.00
36.20
30.00
1
0
0.00
158
CLOVERDALE 765KV - VA
Transmission
138.00
13.09
20.00
0
1
0
0.00
159
CLOVERDALE 765KV - VA
Transmission
69.00
34.50
20.00
0
1
0
0.00
160
CLOVERDALE 765KV - VA
Transmission
765.00
REACTOR
5
500.00
161
CLOVERDALE 765KV - VA
Transmission
138.00
345.00
34.50
500.00
0
1
0
0.00
162
CLOVERDALE 765KV - VA
Transmission
138.00
13.09
34.50
500.00
0
1
0
0.00
163
CLOVERDALE 765KV - VA
Transmission
138.00
345.00
34.50
15.00
0
1
0
0.00
164
CLOVERDALE 765KV - VA
Transmission
138.00
13.09
34.50
15.00
0
1
0
0.00
165
CLOVERDALE 765KV - VA
Transmission
34.50
7.20
1.50
0
1
0
0.00
166
CLOVERDALE 765KV - VA
Transmission
138.00
34.00
20.00
0
1
0
0.00
167
CLOVERDALE 765KV - VA
Transmission
138.00
12.00
12.50
0
1
0
0.00
168
CLOVERDALE 765KV - VA
Transmission
69.00
12.00
5.25
0
1
0
0.00
169
CLOVERDALE 765KV - VA
Transmission
138.00
69.00
13.10
84.00
0
1
0
0.00
170
CLOVERDALE 765KV - VA
Transmission
69.00
34.50
75.00
0
1
0
0.00
171
CLOVERDALE 765KV - VA
Transmission
69.00
13.09
20.00
0
1
0
0.00
172
CLOVERDALE 765KV - VA
Transmission
138.00
13.09
10.50
0
1
0
0.00
173
CLOVERDALE 765KV - VA
Transmission
138.00
70.50
46.00
90.00
0
1
0
0.00
174
CLOVERDALE 765KV - VA
Transmission
138.00
12.00
15.00
0
1
0
0.00
175
CLOVERDALE 765KV - VA
Transmission
69.00
12.00
7.50
0
1
0
0.00
176
CLOVERDALE 765KV - VA
Transmission
69.00
13.09
7.50
0
1
0
0.00
177
CLOVERDALE 765KV - VA
Transmission
69.00
12.00
9.38
0
1
0
0.00
178
CLOVERDALE 765KV - VA
Transmission
69.00
13.09
9.38
0
1
0
0.00
179
CLOVERDALE 765KV - VA
Transmission
765.00
345.00
34.50
5400.00
32
0
0.00
180
CLOVERDALE 765KV - VA
Transmission
765.00
528.00
13.80
1950.00
3
0
0.00
181
CLOVERDALE 765KV - VA (A)
Transmission
138.00
70.50
13.09
78.00
0
1
0
0.00
182
CLOVERDALE 765KV - VA (B)
Transmission
138.00
70.50
13.09
78.00
0
1
0
0.00
183
CLOVERDALE 765KV - VA (C)
Transmission
138.00
70.50
13.09
78.00
0
1
0
0.00
184
CLOVERDALE 765KV - VA (D)
Transmission
138.00
70.50
13.09
78.00
0
1
0
0.00
185
CLOVERDALE 765KV - VA (E)
Transmission
138.00
70.50
36.20
78.00
0
1
0
0.00
186
CLOVERDALE 765KV - VA (F)
Transmission
138.00
70.50
36.20
78.00
0
1
0
0.00
187
CLOVERDALE 765KV - VA (G)
Transmission
138.00
70.50
36.20
78.00
0
1
0
0.00
188
CLOVERDALE 765KV - VA (H)
Transmission
138.00
70.50
36.20
78.00
0
1
0
0.00
189
CLOVERDALE EAST 500KV - VA
Transmission
500.00
345.00
13.80
3500.00
7
0
0.00
190
COAL CREEK - VA
Distribution
69.00
12.00
10.00
1
0
0.00
191
COAL MOUNTAIN - WV
Distribution
46.00
7.20
1.66
2
0
0.00
192
COFFEE - VA
Distribution
138.00
13.09
20.00
1
0
0.00
193
COLLINSVILLE (AP) - VA
Distribution
138.00
13.09
22.40
1
0
0.00
194
CORNING GLASS (AP) - VA
Distribution
69.00
4.00
8.40
1
0
0.00
195
CORNING GLASS (AP) - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
8.10
196
COTTAGEVILLE - WV
Distribution
69.00
12.00
6.25
1
0
0.00
197
COVE ROAD - VA
Distribution
69.00
13.09
20.00
1
0
0.00
198
CRAB ORCHARD - WV
Distribution
46.00
12.00
3.75
1
0
0.00
199
CROOKED CREEK - WV
Distribution
138.00
13.09
20.00
1
0
0.00
200
CROSSROADS (AP) - VA
Distribution
69.00
13.09
22.40
1
0
0.00
201
CROSSROADS (AP) - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
9.60
202
CURRY - WV
Distribution
138.00
13.09
20.00
1
0
0.00
203
DALEWOOD - WV
Distribution
138.00
13.09
20.00
1
0
0.00
204
DAMASCUS - VA
Distribution
69.00
12.00
20.00
1
0
0.00
205
DAMERON - WV
Transmission
138.00
69.00
46.00
129.00
1
0
0.00
206
DAMERON - WV
Transmission
46.00
34.50
20.00
1
0
0.00
207
DAMERON - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
208
DAN RIVER RESEARCH - VA
Distribution
12.00
0.60
0.25
1
0
0.00
209
DAN RIVER RESEARCH - VA
Distribution
69.00
12.00
1.00
1
0
0.00
210
DAN RIVER RESEARCH - VA
Distribution
7.62
0.60
0.50
2
0
0.00
211
DANVILLE - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
57.60
212
DANVILLE - VA
Transmission
138.00
69.00
12.00
115.00
1
0
0.00
213
DARRAH - WV
Transmission
138.00
69.00
34.50
90.00
1
0
0.00
214
DARRAH - WV
Transmission
138.00
13.09
22.40
1
0
0.00
215
DARRAH - WV
Transmission
138.00
34.50
45.50
1
0
0.00
216
DARRAH - WV
Transmission
138.00
34.50
30.00
1
0
0.00
217
DEARINGTON - VA
Distribution
69.00
13.09
25.00
1
0
0.00
218
DEARINGTON - VA
Distribution
69.00
12.00
20.00
1
0
0.00
219
DEARINGTON - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
14.40
220
DEHUE - WV
Distribution
46.00
13.09
9.38
1
0
0.00
221
DINGESS - WV
Distribution
138.00
34.50
30.00
1
0
0.00
222
DISMAL RIVER - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
14.39
223
DISMAL RIVER - VA
Distribution
69.00
12.00
10.50
1
0
0.00
224
DISSTON - VA
Distribution
69.00
4.00
3.13
1
0
0.00
225
DOROTHY - WV
Distribution
46.00
2.30
1.50
3
0
0.00
226
DUBLIN (AP) - VA
Distribution
34.50
12.00
18.76
3
0
0.00
227
DUNBAR - WV
Distribution
46.00
13.09
20.00
1
0
0.00
228
DUPONT (AP) - VA
Distribution
69.00
12.00
4.20
1
0
0.00
229
EAST DANVILLE - VA
Transmission
69.00
12.00
8.40
1
0
0.00
230
EAST DANVILLE - VA
Transmission
138.00
69.50
13.09
60.00
1
0
0.00
231
EAST DANVILLE - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
52.79
232
EAST DANVILLE - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
14.39
233
EAST DANVILLE - VA
Transmission
230.00
138.00
34.50
1500.00
2
0
0.00
234
EAST HUNTINGTON - WV
Transmission
138.00
69.00
34.50
90.00
1
0
0.00
235
EAST HUNTINGTON - WV
Transmission
138.00
34.50
30.00
1
0
0.00
236
EAST HUNTINGTON - WV
Transmission
34.50
12.00
9.38
1
0
0.00
237
EAST LYNCHBURG - VA
Transmission
138.00
69.00
34.50
196.00
1
0
0.00
238
EAST MONUMENT - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
52.79
239
EAST RIVER MOUNTAIN - WV
Distribution
138.00
34.50
9.38
1
0
0.00
240
EDGEMONT - VA
Distribution
138.00
13.09
22.40
1
0
0.00
241
EDWIGHT - WV
Distribution
46.00
7.20
2.49
3
0
0.00
242
ELK CREEK - WV
Distribution
46.00
12.00
3.75
1
0
0.00
243
ELK GARDEN - VA
Distribution
138.00
13.09
7.50
1
0
0.00
244
ELK GARDEN - VA
Distribution
138.00
36.20
30.00
1
0
0.00
245
ELK GARDEN - VA
Distribution
138.00
34.50
30.00
1
0
0.00
246
ELM STREET - VA
Distribution
34.50
0.00
0.00
0.00
STATCAP
1
9.60
247
ELM STREET - VA
Distribution
34.50
12.00
20.00
1
0
0.00
248
ELMO - WV
Distribution
69.00
12.00
5.00
1
0
0.00
249
ESMONT - VA
Distribution
46.00
12.00
4.69
1
0
0.00
250
EXPRESSWAY - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
10.80
251
EXPRESSWAY - VA
Distribution
69.00
12.00
42.40
2
0
0.00
252
FALLING BRANCH - VA
Distribution
138.00
13.09
9.38
1
0
0.00
253
FARADAY 138KV - WV
Distribution
34.50
0.00
0.00
0.00
AIR CORE REACTOR
3
254
FARADAY 138KV - WV
Distribution
34.50
0.00
0.00
0.00
STATCAP
1
6.00
255
FIELDALE - VA
Transmission
138.00
70.50
36.20
78.00
1
0
0.00
256
FIELDALE - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
2
100.80
257
FIELDALE - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
26.39
258
FIELDCREST MILLS - VA
Distribution
69.00
4.00
20.00
1
0
0.00
259
FLATWOOD - WV
Distribution
138.00
34.50
30.00
1
0
0.00
260
FLATWOOD - WV
Distribution
138.00
12.47
22.40
1
0
0.00
261
FLETCHERS RIDGE - VA
Distribution
138.00
13.09
10.50
1
0
0.00
262
FLOYD - VA
Transmission
138.00
69.00
34.50
56.00
1
0
0.00
263
FLOYD - VA
Transmission
138.00
13.09
10.50
1
0
0.00
264
FLOYD - VA
Transmission
138.00
12.00
9.38
1
0
0.00
265
FOREST (AP) - VA
Distribution
138.00
13.09
42.40
2
0
0.00
266
FOUR POLE CREEK - WV
Distribution
34.50
4.16
4.50
3
0
0.00
267
FRANKLIN - VA
Distribution
138.00
13.09
22.40
1
0
0.00
268
FRANKLIN - VA
Distribution
138.00
34.50
30.00
1
0
0.00
269
FRANKLIN STREET - VA
Distribution
34.50
12.00
6.25
1
0
0.00
270
FREMONT (AP) - VA
Transmission
138.00
70.50
13.09
208.00
2
0
0.00
271
FRIES - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
14.40
272
FRIES - VA
Distribution
69.00
12.00
10.28
2
0
0.00
273
FULKS - WV
Distribution
34.50
13.09
9.38
1
0
0.00
274
FULKS - WV
Distribution
34.50
34.50
5.00
25.00
1
0
0.00
275
FULKS - WV
Distribution
34.50
34.50
6.50
30.00
1
0
0.00
276
GALAX - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
2
26.38
277
GALAX - VA (A)
Distribution
69.00
12.00
22.40
1
0
0.00
278
GALAX - VA
Distribution
69.00
12.00
22.40
1
0
0.00
279
GALLAGHER - WV
Distribution
46.00
12.00
4.69
1
0
0.00
280
GARDEN CREEK - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
50.40
281
GARDEN CREEK - VA
Transmission
138.00
69.50
13.09
84.00
1
0
0.00
282
GARDEN CREEK - VA
Transmission
69.00
12.00
22.40
1
0
0.00
283
GAULEY MOUNTAIN - WV
Distribution
69.00
12.00
8.40
1
0
0.00
284
GILBERT - WV
Distribution
46.00
12.00
20.00
1
0
0.00
285
GILBERT - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
9.60
286
GLADE - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
9.60
287
GLADE - VA
Distribution
69.00
34.50
30.00
1
0
0.00
288
GLADE - VA
Distribution
69.00
12.00
10.50
1
0
0.00
289
GLAMORGAN - VA
Distribution
34.50
4.00
9.38
1
0
0.00
290
GLEN LYN - VA
Transmission
138.00
13.20
18.75
3
0
0.00
291
GLEN LYN - VA
Transmission
88.00
69.00
13.10
84.00
0
1
0
0.00
292
GLEN LYN - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
4
203.99
293
GLEN WHITE - WV
Distribution
46.00
12.00
6.25
1
0
0.00
294
GLENWOOD (AP) - VA
Distribution
12.00
0.24
0.33
2
0
0.00
295
GLENWOOD (AP) - VA
Distribution
13.20
0.24
0.17
1
0
0.00
296
GLENWOOD (AP) - VA
Distribution
12.00
0.24
0.17
0
1
0
0.00
297
GLENWOOD (AP) - VA
Distribution
23.00
12.00
9.40
1
0
0.00
298
GLENWOOD (AP) - VA
Distribution
23.00
12.00
3.75
0
1
0
0.00
299
GOMINGO - VA
Distribution
138.00
13.09
22.40
1
0
0.00
300
GRAPEVINE - WV
Distribution
46.00
7.20
6.99
6
0
0.00
301
GRASSY FORK - WV
Distribution
138.00
34.50
20.00
1
0
0.00
302
GRAVES MILL - VA
Distribution
138.00
13.09
40.00
2
0
0.00
303
GREENBRIER - WV
Distribution
69.00
13.09
25.00
1
0
0.00
304
GREENBRIER METERING - WV
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
28.79
305
GRUNDY - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
13.19
306
GRUNDY - VA
Transmission
69.00
12.00
10.50
1
0
0.00
307
GRUNDY - VA
Transmission
69.00
34.50
25.00
1
0
0.00
308
GUTHRIE - WV
Distribution
46.00
34.50
25.00
1
0
0.00
309
HALES BRANCH - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
14.39
310
HALES BRANCH - VA
Transmission
138.00
69.00
12.00
84.00
1
0
0.00
311
HALES BRANCH - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
50.40
312
HALLS RIDGE - WV
Distribution
138.00
34.50
1
0
0.00
313
HAMPTON - WV
Distribution
46.00
7.20
4.50
3
0
0.00
314
HAMPTON - WV
Distribution
46.00
12.00
3.75
1
0
0.00
315
HANCOCK - VA
Transmission
34.50
0.00
0.00
0.00
STATCAP
1
12.00
316
HANCOCK - VA
Transmission
138.00
34.50
11.00
45.00
3
0
0.00
317
HANCOCK - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
50.40
318
HANCOCK - VA
Transmission
34.50
36.20
15.00
1
0
0.00
319
HANCOCK - VA
Transmission
138.00
69.00
34.50
128.80
1
0
0.00
320
HANS MEADOW - VA
Distribution
69.00
13.09
25.00
1
0
0.00
321
HANS MEADOW - VA
Distribution
69.00
12.00
10.50
0
1
0
0.00
322
HANS MEADOW - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
17.20
323
HANSONVILLE - VA
Distribution
138.00
13.09
20.00
1
0
0.00
324
HARDY - WV
Distribution
46.00
7.20
4.50
3
0
0.00
325
HARMON BRANCH - WV
Distribution
138.00
12.00
15.00
1
0
0.00
326
HARTLAND - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
5.40
327
HARTLAND - WV
Distribution
46.00
13.09
12.50
1
0
0.00
328
HASH RIDGE - WV
Distribution
138.00
34.50
30.00
1
0
0.00
329
HAYSI - VA
Distribution
69.00
12.00
20.00
1
0
0.00
330
HENRY S.D. - VA
Distribution
34.50
13.00
3.75
1
0
0.00
331
HEWETT - WV
Distribution
46.00
12.00
10.50
1
0
0.00
332
HICKMAN - VA
Distribution
69.00
13.09
20.00
1
0
0.00
333
HICKORY GAP - WV
Distribution
34.50
12.00
2.50
1
0
0.00
334
HILL - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
13.19
335
HILL - VA
Transmission
138.00
69.00
34.50
40.00
1
0
0.00
336
HILL - VA
Transmission
138.00
13.09
8.40
1
0
0.00
337
HILLMAN HIGHWAY - VA
Distribution
69.00
12.00
22.40
1
0
0.00
338
HILLMAN HIGHWAY - VA
Distribution
69.00
13.09
25.00
1
0
0.00
339
HILLSVILLE - VA
Distribution
34.50
12.00
6.75
2
0
0.00
340
HINTON (AP) - WV
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
43.20
341
HOPKINS - WV
Transmission
138.00
0.00
0.00
0.00
AIR CORE REACTOR
4
0.00
342
HOPKINS - WV
Transmission
138.00
69.00
46.00
56.00
1
0
0.00
343
HOPKINS - WV
Transmission
138.00
34.50
20.00
1
0
0.00
344
HOPKINS - WV
Transmission
138.00
13.09
20.00
1
0
0.00
345
HOPKINS FORK - WV
Distribution
46.00
7.20
2.49
3
0
0.00
346
HUBBARDSTOWN - WV
Distribution
138.00
34.50
20.00
1
0
0.00
347
HUFF CREEK - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
348
HUFF CREEK - WV
Transmission
138.00
69.00
46.00
130.00
1
0
0.00
349
HUFF CREEK - WV
Transmission
46.00
13.09
20.00
1
0
0.00
350
HUFFMAN - VA
Distribution
138.00
0.00
0.00
0.00
STATCAP
1
28.80
351
HUGHESTON - WV
Distribution
46.00
2.40
2.50
3
0
0.00
352
HUNTINGTON COURT - VA
Distribution
138.00
69.00
34.50
175.00
1
0
0.00
353
HUNTINGTON COURT - VA
Distribution
138.00
0.00
0.00
0.00
STATCAP
1
64.80
354
HUNTINGTON COURT - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
28.80
355
HUNTINGTON COURT - VA
Distribution
69.00
12.00
20.00
1
0
0.00
356
HUNTINGTON COURT - VA
Distribution
69.00
34.50
75.00
1
0
0.00
357
HURLEY - VA
Distribution
69.00
12.00
22.40
1
0
0.00
358
HURRICANE - WV
Distribution
69.00
12.00
25.00
1
0
0.00
359
HURRICANE - WV
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
21.60
360
INDEPENDENCE - VA
Distribution
69.00
12.00
10.50
1
0
0.00
361
INDEPENDENCE - VA
Distribution
69.00
34.50
20.00
1
0
0.00
362
INGLES - VA
Distribution
69.00
13.09
20.00
1
0
0.00
363
INGLES - VA
Distribution
69.00
34.50
50.00
1
0
0.00
364
INGLES - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
14.40
365
ITMANN - WV
Distribution
138.00
13.09
22.40
1
0
0.00
366
IVY HILL - VA
Distribution
138.00
13.09
20.00
1
0
0.00
367
JACKSONS FERRY - VA
Transmission
765.00
138.00
13.80
1750.00
8
0
0.00
368
JACKSONS FERRY - VA
Transmission
765.00
20.65
13.80
1
0
0.00
369
JACKSONS FERRY - VA
Transmission
765.00
13.80
250.00
2
0
0.00
370
JACKSONS FERRY - VA
Transmission
765.00
138.00
250.00
2
0
0.00
371
JACKSONS FERRY - VA
Transmission
13.20
0.00
0.00
0.00
STATCAP
1
3.59
372
JACKSONS FERRY - VA
Transmission
765.00
250.00
2
0
0.00
373
JACKSONS FERRY - VA
Transmission
765.00
500.00
13.80
500.00
3
0
0.00
374
JACKSONS FERRY - VA
Transmission
20.78
0.00
0.00
0.00
STATCAP
3
888.84
375
JARROLD - WV
Distribution
46.00
13.09
5.00
1
0
0.00
376
JEWELL RIDGE - VA
Distribution
69.00
12.00
9.38
1
0
0.00
377
JIM BRANCH - WV
Transmission
69.00
12.00
10.00
1
0
0.00
378
JIM BRANCH - WV
Transmission
138.00
69.00
46.00
128.80
1
0
0.00
379
JOHNSONS LANE - WV
Distribution
34.50
34.50
5.00
25.00
1
0
0.00
380
JOSHUA FALLS - VA
Transmission
765.00
138.00
13.80
750.00
3
0
0.00
381
JUBAL EARLY - VA
Transmission
138.00
70.50
36.20
108.00
2
0
0.00
382
JUBAL EARLY - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
43.20
383
KANAWHA CITY - WV
Distribution
46.00
12.00
22.40
1
0
0.00
384
KANAWHA CITY - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
15.60
385
KANAWHA RIVER - WV
Transmission
138.00
13.09
20.00
1
0
0.00
386
KANAWHA RIVER - WV
Transmission
138.00
0.00
0.00
0.00
STATCAP
2
115.20
387
KANAWHA RIVER - WV
Transmission
345.00
138.00
13.80
1
0
0.00
388
KENOVA - WV
Transmission
138.00
69.00
46.00
150.00
0
1
0
0.00
389
KENOVA - WV
Transmission
34.50
4.00
3.75
1
0
0.00
390
KENOVA - WV
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
14.40
391
KENOVA - WV
Transmission
138.00
34.50
30.00
1
0
0.00
392
KENOVA - WV
Transmission
138.00
69.00
34.50
200.00
1
0
0.00
393
KENOVA - WV
Transmission
34.50
13.09
9.38
1
0
0.00
394
KILLARNEY - WV
Distribution
46.00
7.20
1.16
3
0
0.00
395
KINCAID - WV
Transmission
138.00
69.00
46.00
84.00
1
0
0.00
396
KNOTTY POPLAR - VA
Distribution
69.00
12.00
6.25
1
0
0.00
397
KOPPERSTON - WV
Distribution
138.00
13.09
20.00
1
0
0.00
398
KUMIS - VA
Distribution
138.00
13.09
22.40
1
0
0.00
399
LAKE FOREST - VA
Distribution
138.00
36.20
30.00
1
0
0.00
400
LAKEVIEW - WV
Distribution
138.00
13.09
20.00
1
0
0.00
401
LAKIN - WV
Transmission
138.00
69.00
12.00
90.00
1
0
0.00
402
LAKIN - WV
Transmission
138.00
13.09
20.00
1
0
0.00
403
LATROBE - WV
Distribution
46.00
7.20
4.50
3
0
0.00
404
LAVALETTE - WV
Distribution
138.00
34.50
30.00
1
0
0.00
405
LAYLAND - WV
Distribution
69.00
13.09
2.50
1
0
0.00
406
LEBANON - VA
Distribution
138.00
13.09
22.40
1
0
0.00
407
LEIVASY - WV
Distribution
69.00
12.00
8.40
1
0
0.00
408
LICK FORK - VA
Distribution
69.00
34.50
10.50
1
0
0.00
409
LOCK LANE - WV
Distribution
69.00
12.00
6.25
1
0
0.00
410
LOCKHART - VA
Distribution
138.00
13.04
20.00
1
0
0.00
411
LOGAN - WV
Transmission
138.00
13.09
22.40
1
0
0.00
412
LOGAN - WV
Transmission
138.00
0.00
0.00
0.00
STATCAP
2
115.19
413
LONESOME PINE - VA
Distribution
138.00
13.09
22.40
1
0
0.00
414
LOONEY CREEK - VA
Transmission
138.00
69.00
34.50
90.00
1
0
0.00
415
LOUDENDALE - WV
Distribution
46.00
12.00
10.50
1
0
0.00
416
LOUP CREEK - WV
Distribution
46.00
12.00
3.00
1
0
0.00
417
LUKENS - VA
Distribution
69.00
12.00
20.00
1
0
0.00
418
LUKENS - VA
Distribution
69.00
13.09
20.00
1
0
0.00
419
MAMMOTH - WV
Distribution
46.00
12.00
3.75
1
0
0.00
420
MARMET - WV
Distribution
46.00
12.00
7.00
1
0
0.00
421
MARSH FORK - WV
Distribution
46.00
12.00
10.50
1
0
0.00
422
MARTINSVILLE - VA
Transmission
138.00
34.50
30.00
1
0
0.00
423
MARTINSVILLE - VA
Transmission
138.00
70.50
36.20
108.00
2
0
0.00
424
MASON CREEK - VA
Distribution
69.00
12.00
25.00
1
0
0.00
425
MATT FUNK 138KV - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
2
147.60
426
MATT FUNK 345KV - VA
Transmission
345.00
138.00
13.10
672.00
1
0
0.00
427
MATT FUNK 345KV - VA
Transmission
345.00
138.00
34.50
675.00
1
0
0.00
428
MCDOWELL - WV
Transmission
34.50
13.20
7.50
1
0
0.00
429
MCGRAWS - WV
Distribution
46.00
13.09
12.50
1
0
0.00
430
MCROSS - WV
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
9.60
431
MCROSS - WV
Distribution
69.00
34.50
30.00
1
0
0.00
432
MEADOW BRIDGE - WV
Distribution
69.00
34.50
8.40
1
0
0.00
433
MEADOWVIEW - VA
Distribution
138.00
13.09
20.00
1
0
0.00
434
MEADOWVIEW - VA
Distribution
138.00
69.00
34.50
56.00
1
0
0.00
435
MELROSE - VA
Distribution
69.00
12.00
22.40
1
0
0.00
436
MERRIMAC - VA
Transmission
138.00
69.00
12.00
128.00
1
0
0.00
437
MERRIMAC - VA
Transmission
138.00
69.00
13.09
78.00
1
0
0.00
438
MERRIMAC - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
27.00
439
MERRITTS CREEK - WV
Distribution
138.00
36.20
30.00
1
0
0.00
440
MIDDLE BURNING CREEK - WV
Distribution
34.50
12.00
5.00
1
0
0.00
441
MIDKIFF - WV
Distribution
138.00
34.50
20.00
1
0
0.00
442
MIDWAY (AP) - VA
Distribution
69.00
4.00
12.25
2
0
0.00
443
MIKES RUN - WV
Distribution
46.00
12.00
3.75
1
0
0.00
444
MILBURN - WV
Distribution
46.00
7.20
1.50
3
0
0.00
445
MILTON - WV
Transmission
69.00
36.20
30.00
1
0
0.00
446
MILTON - WV
Transmission
138.00
13.09
25.00
2
0
0.00
447
MILTON - WV
Transmission
138.00
69.00
34.50
90.00
1
0
0.00
448
MINK SHOALS - WV
Distribution
69.00
13.09
20.00
1
0
0.00
449
MINNIX MOUNTAIN - WV
Distribution
138.00
34.00
25.00
1
0
0.00
450
MOHAWK RUBBER - VA
Distribution
69.00
2.40
25.00
2
0
0.00
451
MONEL - VA
Distribution
138.00
13.09
20.00
1
0
0.00
452
MONETA - VA
Distribution
138.00
34.50
30.00
1
0
0.00
453
MONROE (AP) - VA
Distribution
69.00
13.09
20.00
1
0
0.00
454
MONTEREY - VA
Distribution
69.00
12.00
10.50
1
0
0.00
455
MONTGOMERY - WV
Distribution
46.00
12.00
22.40
1
0
0.00
456
MORGANS CUT - VA
Transmission
138.00
69.00
34.50
200.00
1
0
0.00
457
MORGANS CUT - VA
Transmission
138.00
69.00
34.50
84.00
0
1
0
0.00
458
MORGANS CUT - VA
Transmission
34.50
0.00
0.00
0.00
STATCAP
1
13.50
459
MORRIS NOVELTY - VA
Distribution
34.50
12.00
3.75
1
0
0.00
460
MORRIS NOVELTY - VA
Distribution
34.50
0.00
0.00
0.00
STATCAP
1
15.60
461
MOSELEY - VA
Transmission
138.00
70.50
13.09
1674.00
27
0
0.00
462
MOSS - VA
Distribution
69.00
12.00
8.40
1
0
0.00
463
MOUNT AIRY - VA
Distribution
138.00
34.50
20.00
1
0
0.00
464
MOUNT UNION - VA
Transmission
69.00
34.50
30.00
1
0
0.00
465
MOUNT UNION - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
13.19
466
MOUNT UNION - VA
Transmission
69.00
12.00
20.00
1
0
0.00
467
MOUNT VIEW - VA
Distribution
69.00
12.00
22.40
1
0
0.00
468
MUD FORK - WV
Distribution
138.00
13.09
22.40
1
0
0.00
469
MUDLICK - VA
Distribution
69.00
12.00
22.40
1
0
0.00
470
MULLENS - WV
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
50.40
471
MULLENS - WV
Transmission
138.00
34.50
25.00
1
0
0.00
472
MULLENS - WV
Transmission
138.00
46.00
30.00
1
0
0.00
473
MULLENS TOWN - WV
Distribution
34.50
4.00
4.70
1
0
0.00
474
NAGEL - TN
Transmission
500.00
230.00
13.80
750.00
3
0
0.00
475
NAGEL - TN
Transmission
138.00
34.50
30.00
1
0
0.00
476
NAGEL - TN
Transmission
500.00
138.00
13.80
3
0
0.00
477
NEECE CREEK - VA
Distribution
69.00
12.00
8.40
1
0
0.00
478
NEW CASTLE - VA
Distribution
34.50
12.00
7.00
1
0
0.00
479
NEW CASTLE - VA
Distribution
34.50
0.00
0.00
0.00
STATCAP
1
3.59
480
NEW HOPE (AP) - WV
Distribution
138.00
34.50
25.00
1
0
0.00
481
NEW HOPE (AP) - WV
Distribution
138.00
13.09
22.40
1
0
0.00
482
NEW LONDON - VA
Transmission
138.00
34.50
30.00
1
0
0.00
483
NITRO - WV
Distribution
69.00
12.00
20.00
1
0
0.00
484
NORTH BECKLEY - WV
Distribution
138.00
34.50
30.00
1
0
0.00
485
NORTH BECKLEY - WV
Distribution
138.00
13.09
25.00
1
0
0.00
486
NORTH BLACKSBURG - VA
Transmission
138.00
69.00
12.00
128.80
1
0
0.00
487
NORTH BLACKSBURG - VA
Transmission
138.00
13.09
22.40
1
0
0.00
488
NORTH CLAYTOR - VA
Transmission
138.00
69.00
34.50
200.00
1
0
0.00
489
NORTH CLAYTOR - VA
Transmission
138.00
69.00
34.50
84.00
0
1
0
0.00
490
NORTH POINTE - WV
Distribution
138.00
34.50
20.00
1
0
0.00
491
OAK HILL (AP) - WV
Distribution
69.00
12.00
22.40
1
0
0.00
492
OAK LEVEL - VA
Distribution
138.00
13.09
20.00
1
0
0.00
493
OCEANA - WV
Distribution
46.00
12.00
16.75
2
0
0.00
494
OPOSSUM CREEK - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
2
105.58
495
ORCHARD - VA
Distribution
34.50
12.00
6.25
1
0
0.00
496
ORTIN - WV
Distribution
138.00
13.09
20.00
1
0
0.00
497
PACKSVILLE - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
498
PAD FORK - WV
Distribution
138.00
34.50
20.00
1
0
0.00
499
PANTHER - WV
Distribution
46.00
7.20
4.50
3
0
0.00
500
PARK HILL - WV
Distribution
138.00
13.09
22.40
1
0
0.00
501
PATRICK STREET - WV
Distribution
46.00
13.09
20.00
1
0
0.00
502
PATRIOT CENTRE - VA
Distribution
138.00
34.50
30.00
1
0
0.00
503
PAX BRANCH 138KV - WV
Transmission
138.00
46.00
216.00
4
0
0.00
504
PAX BRANCH 138KV - WV
Transmission
138.00
13.09
20.00
2
0
0.00
505
PAX BRANCH 138KV - WV
Transmission
138.00
12.00
20.00
2
0
0.00
506
PEAK CREEK - VA
Distribution
138.00
34.50
30.00
1
0
0.00
507
PEAK CREEK - VA
Distribution
138.00
13.09
20.00
1
0
0.00
508
PEAKLAND - VA
Distribution
69.00
12.00
20.00
1
0
0.00
509
PEAKSVIEW - VA
Transmission
138.00
69.00
34.50
130.00
1
0
0.00
510
PEARISBURG - VA
Distribution
34.50
12.00
6.25
1
0
0.00
511
PEMBERTON - WV
Transmission
46.00
4.00
5.00
1
0
0.00
512
PEMBERTON - WV
Transmission
138.00
69.00
46.00
90.00
1
0
0.00
513
PENHOOK - VA
Distribution
138.00
34.50
30.00
1
0
0.00
514
PERKINS PARK - VA
Distribution
69.00
12.00
20.00
1
0
0.00
515
PETERS MOUNTAIN - VA
Distribution
138.00
34.50
30.00
1
0
0.00
516
PEYTONA - WV
Distribution
46.00
13.09
10.50
1
0
0.00
517
PHOENIX - VA
Distribution
46.00
7.20
1.00
3
0
0.00
518
PIGEON CREEK - WV
Distribution
138.00
34.50
60.00
2
0
0.00
519
PINE CREEK - WV
Distribution
138.00
13.09
12.50
1
0
0.00
520
PINE GAP - WV
Distribution
46.00
12.00
3.00
1
0
0.00
521
PINNACLE CREEK - WV
Distribution
138.00
34.50
9.38
1
0
0.00
522
PINNACLE CREEK - WV
Distribution
138.00
34.50
12.00
13.30
1
0
0.00
523
PIPERS GAP - VA
Distribution
138.00
36.20
30.00
1
0
0.00
524
PIPERS GAP - VA
Distribution
138.00
34.00
30.00
1
0
0.00
525
PLANT ROAD - WV
Distribution
69.00
12.00
22.40
1
0
0.00
526
PLANTATION PIPELINE - VA
Distribution
34.50
7.50
4.50
3
0
0.00
527
POAGES MILL - VA
Distribution
138.00
13.09
20.00
1
0
0.00
528
POINT PLEASANT - WV
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
9.60
529
POLEYARD - WV
Distribution
138.00
13.09
25.00
1
0
0.00
530
POPLAR FORK - WV
Distribution
138.00
13.09
20.00
1
0
0.00
531
POPLAR GAP - WV
Distribution
46.00
7.20
4.50
3
0
0.00
532
POUND - VA
Distribution
69.00
12.00
6.25
1
0
0.00
533
POUND - VA
Distribution
69.00
34.50
25.00
1
0
0.00
534
POWELLTON - WV
Distribution
46.00
7.20
2.49
3
0
0.00
535
PRICES FORK - VA
Distribution
0.00
0.00
0.00
STATCAP
1
536
PRICES FORK - VA
Distribution
69.00
12.00
22.40
1
0
0.00
537
PRICES FORK - VA
Distribution
69.00
13.09
25.00
1
0
0.00
538
PRINCE - WV
Distribution
69.00
13.09
5.25
1
0
0.00
539
PRINCETON - WV
Distribution
34.50
12.00
20.00
2
0
0.00
540
PROGRESS PARK - VA
Distribution
138.00
0.00
0.00
0.00
STATCAP
1
57.60
541
PROGRESS PARK - VA
Distribution
138.00
36.20
30.00
1
0
0.00
542
PROGRESS PARK - VA
Distribution
138.00
34.50
30.00
1
0
0.00
543
PUTNAM VILLAGE - WV
Distribution
69.00
13.09
20.00
1
0
0.00
544
RADFORD - VA
Distribution
34.50
0.00
0.00
0.00
STATCAP
1
10.80
545
RAGLAND - WV
Distribution
138.00
34.50
25.00
1
0
0.00
546
RAVENSWOOD - WV
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
14.40
547
RAVENSWOOD - WV
Distribution
69.00
13.09
25.00
1
0
0.00
548
RED HILL - VA
Distribution
138.00
13.09
8.40
1
0
0.00
549
RENSFORD - WV
Distribution
138.00
34.50
25.00
1
0
0.00
550
REUSENS - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
57.60
551
REUSENS - VA
Transmission
138.00
69.00
13.09
130.00
1
0
0.00
552
REUSENS - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
13.50
553
RICH ACRES - VA
Distribution
69.00
34.50
30.00
1
0
0.00
554
RICH CREEK - WV
Distribution
46.00
12.00
10.50
1
0
0.00
555
RICHLANDS - VA
Transmission
138.00
69.00
13.09
78.00
1
0
0.00
556
RICHLANDS - VA
Transmission
138.00
69.00
13.10
130.00
1
0
0.00
557
RIDGEWAY - VA
Transmission
138.00
69.00
7.20
35.00
1
0
0.00
558
RIDGEWAY - VA
Transmission
138.00
69.00
4.00
40.00
1
0
0.00
559
RIDGEWAY - VA
Transmission
138.00
REACTOR
48
3,230.40
560
RIDGEWAY - VA
Transmission
138.00
34.50
25.00
1
0
0.00
561
RIDGEWAY - VA
Transmission
138.00
13.09
9.38
0
1
0
0.00
562
RIGIS - VA
Transmission
138.00
69.00
12.00
115.00
1
0
0.00
563
RIPLEY - WV
Distribution
138.00
69.00
13.09
78.00
1
0
0.00
564
RIPLEY - WV
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
9.60
565
RIPLEY - WV
Distribution
69.00
34.50
25.00
1
0
0.00
566
RIPLEY - WV
Distribution
69.00
13.09
12.50
1
0
0.00
567
RIVERBEND - VA
Distribution
69.00
12.00
9.38
1
0
0.00
568
RIVERBEND - VA
Distribution
69.00
12.00
7.00
1
0
0.00
569
RIVERBEND - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
14.40
570
RIVERMONT - VA
Distribution
69.00
12.00
20.00
1
0
0.00
571
RIVERVILLE - VA
Distribution
138.00
13.09
104.00
3
0
0.00
572
RIVERVILLE - VA
Distribution
138.00
0.00
0.00
0.00
STATCAP
1
32.40
573
ROANOKE (AP) - VA
Transmission
138.00
34.50
30.00
1
0
0.00
574
ROANOKE (AP) - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
2
122.39
575
ROANOKE (AP) - VA
Transmission
34.50
0.00
0.00
0.00
STATCAP
1
7.19
576
ROANOKE (AP) - VA
Transmission
138.00
13.09
20.00
1
0
0.00
577
ROANOKE (AP) - VA
Transmission
138.00
69.00
12.00
130.00
1
0
0.00
578
ROANOKE ELECTRIC STEEL - VA
Distribution
138.00
34.50
197.00
2
0
0.00
579
ROANOKE ELECTRIC STEEL - VA
Distribution
138.00
34.50
16.67
0
1
0
0.00
580
ROANOKE ELECTRIC STEEL - VA
Distribution
34.50
0.00
0.00
0.00
STATCAP
4
278.50
581
ROBINSON - WV
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
13.19
582
ROBINSON - WV
Distribution
69.00
12.00
10.40
1
0
0.00
583
RONDA - WV
Distribution
46.00
12.00
3.75
1
0
0.00
584
RONDA - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
7.20
585
RURAL RETREAT - VA
Distribution
138.00
34.50
25.00
1
0
0.00
586
RUSTBURG - VA
Distribution
138.00
13.09
20.00
1
0
0.00
587
RUTH - WV
Distribution
138.00
13.09
20.00
1
0
0.00
588
SALTVILLE - VA
Transmission
138.00
69.00
34.50
56.00
1
0
0.00
589
SALTVILLE - VA
Transmission
138.00
34.50
20.00
1
0
0.00
590
SALTVILLE - VA
Transmission
138.00
13.09
10.50
1
0
0.00
591
SCARBRO - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
592
SCHUYLER - VA
Distribution
46.00
7.20
0.83
0
1
0
0.00
593
SCHUYLER - VA
Distribution
46.00
7.20
2.01
3
0
0.00
594
SCOTTSVILLE (AP) - VA
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
3.59
595
SCOTTSVILLE (AP) - VA
Transmission
46.00
13.09
9.38
1
0
0.00
596
SCOTTSVILLE (AP) - VA
Transmission
46.00
12.00
5.00
0
1
0
0.00
597
SCOTTSVILLE (AP) - VA
Transmission
138.00
46.00
40.00
3
0
0.00
598
SEVENTH STREET - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
14.40
599
SEVENTH STREET - VA
Distribution
69.00
12.00
69.80
3
0
0.00
600
SHABDUE - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
601
SHARPLES - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
9.60
602
SHARPLES - WV
Distribution
46.00
12.00
4.69
1
0
0.00
603
SHAWSVILLE - VA
Distribution
138.00
13.09
10.50
1
0
0.00
604
SHEFFIELD (AP) - VA
Distribution
138.00
34.50
30.00
1
0
0.00
605
SHERIDAN (AP) - WV
Distribution
69.00
12.00
22.40
1
0
0.00
606
SHERWILL - VA
Distribution
69.00
12.00
20.00
1
0
0.00
607
SHIPMAN - VA
Distribution
46.00
12.00
4.70
1
0
0.00
608
SISSON - WV
Distribution
138.00
34.50
30.00
1
0
0.00
609
SKEGGS BRANCH - VA
Transmission
138.00
69.00
4.00
30.00
1
0
0.00
610
SKIMMER - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
26.40
611
SKIMMER - VA
Distribution
115.00
69.00
112.00
2
0
0.00
612
SKIMMER - VA
Distribution
69.00
12.00
30.00
1
0
0.00
613
SKIN FORK - WV
Distribution
46.00
12.00
8.40
1
0
0.00
614
SKIN FORK - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
9.60
615
SLAB FORK - WV
Distribution
46.00
7.20
0.99
3
0
0.00
616
SLATE CREEK - VA
Distribution
69.00
13.09
20.00
1
0
0.00
617
SMITH LANE - VA
Distribution
34.50
12.00
6.25
1
0
0.00
618
SMYTH - VA
Distribution
138.00
36.20
30.00
1
0
0.00
619
SMYTH - VA
Distribution
138.00
34.50
25.00
1
0
0.00
620
SOLITE - VA
Distribution
69.00
12.00
5.25
1
0
0.00
621
SOPHIA - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
14.40
622
SOURWOOD - WV
Distribution
138.00
13.09
8.40
1
0
0.00
623
SOUTH BLUEFIELD - WV
Transmission
138.00
13.09
30.00
1
0
0.00
624
SOUTH BUFFALO - WV
Distribution
138.00
13.09
60.00
3
0
0.00
625
SOUTH BUFFALO - WV
Distribution
138.00
36.20
30.00
1
0
0.00
626
SOUTH CHARLESTON - WV
Distribution
46.00
12.00
22.40
1
0
0.00
627
SOUTH CHRISTIANSBURG - VA
Transmission
138.00
69.00
12.00
56.00
1
0
0.00
628
SOUTH CHRISTIANSBURG - VA
Transmission
138.00
13.09
20.00
1
0
0.00
629
SOUTH HILLS - WV
Distribution
46.00
12.00
22.40
1
0
0.00
630
SOUTH HILLS - WV
Distribution
46.00
13.09
25.00
1
0
0.00
631
SOUTH LYNCHBURG - VA
Transmission
138.00
13.09
40.00
2
0
0.00
632
SOUTH LYNCHBURG - VA
Transmission
138.00
70.50
36.20
78.00
1
0
0.00
633
SOUTH LYNCHBURG - VA
Transmission
138.00
69.00
34.50
50.00
1
0
0.00
634
SOUTH NEAL - WV
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
14.40
635
SOUTH NEAL - WV
Distribution
69.00
12.00
40.00
2
0
0.00
636
SOUTH PRINCETON - WV
Distribution
138.00
34.50
55.00
2
0
0.00
637
SOUTHRIDGE - WV
Distribution
138.00
13.09
20.00
1
0
0.00
638
SPEEDWAY - WV
Distribution
138.00
34.50
30.00
1
0
0.00
639
SPORN 138KV - WV
Transmission
138.00
13.09
20.00
1
0
0.00
640
SPORN 345KV - WV
Transmission
345.00
137.50
13.80
1350.00
3
0
0.00
641
SPRIGG - WV
Transmission
138.00
69.00
46.00
84.00
1
0
0.00
642
SPRIGG - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
643
SPRIGG - WV
Transmission
138.00
13.20
12.00
9.38
1
0
0.00
644
SPRIGG - WV
Transmission
138.00
34.50
25.00
1
0
0.00
645
SPRIGG - WV
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
72.00
646
SPRING CREEK - VA
Distribution
138.00
13.09
21.00
2
0
0.00
647
ST. ALBANS - WV
Distribution
138.00
13.09
50.00
2
0
0.00
648
STANLEYTOWN - VA
Distribution
69.00
12.00
22.40
1
0
0.00
649
STARKEY - VA
Distribution
138.00
13.09
40.00
2
0
0.00
650
STOCKTON - VA
Distribution
138.00
34.50
30.00
1
0
0.00
651
STONE BRANCH - WV
Distribution
138.00
34.50
25.00
1
0
0.00
652
STONE BRANCH - WV
Distribution
138.00
13.09
20.00
1
0
0.00
653
STOTESBURY - WV
Distribution
138.00
13.09
10.50
1
0
0.00
654
STUART - VA
Distribution
69.00
0.00
0.00
0.00
STATCAP
1
10.80
655
STUART - VA
Distribution
69.00
34.50
30.00
1
0
0.00
656
STUART - VA
Distribution
69.00
12.00
10.50
1
0
0.00
657
SUN MINE - WV
Distribution
46.00
12.00
20.00
1
0
0.00
658
SUNDIAL - WV
Transmission
138.00
69.00
46.00
90.00
1
0
0.00
659
SUNDIAL - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
660
SUNSCAPE - VA
Distribution
138.00
12.00
20.00
1
0
0.00
661
SWITCHBACK - WV
Transmission
138.00
34.50
25.00
1
0
0.00
662
SWITCHBACK - WV
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
50.40
663
TACKETT CREEK - WV
Distribution
138.00
13.09
25.00
1
0
0.00
664
TANK HILL - VA
Distribution
138.00
13.09
40.00
2
0
0.00
665
TAZEWELL - VA
Transmission
34.50
12.00
6.25
1
0
0.00
666
TAZEWELL - VA
Transmission
34.50
13.00
6.25
1
0
0.00
667
TAZEWELL - VA
Transmission
138.00
34.50
30.00
1
0
0.00
668
TAZEWELL - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
28.80
669
TEAYS - WV
Distribution
69.00
12.00
22.40
1
0
0.00
670
TECH DRIVE - VA
Distribution
138.00
12.00
20.00
1
0
0.00
671
THOMAS (AP) - VA
Distribution
34.50
7.20
3.00
3
0
0.00
672
THORNTON - VA
Distribution
138.00
34.50
12.00
7.50
1
0
0.00
673
THORNTON - VA
Distribution
138.00
13.09
9.38
1
0
0.00
674
TOMS FORK - WV
Distribution
46.00
0.00
0.00
0.00
STATCAP
1
9.60
675
TOMS FORK - WV
Distribution
46.00
12.00
4.69
1
0
0.00
676
TONEY FORK - WV
Distribution
46.00
12.00
8.40
1
0
0.00
677
TOWER 117 - WV
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
13.19
678
TRAIL FORK - WV
Distribution
138.00
13.09
12.50
1
0
0.00
679
TRAMMEL - VA
Transmission
69.00
12.00
6.25
1
0
0.00
680
TRAP HILL - WV
Distribution
46.00
36.20
40.00
2
0
0.00
681
TRI-STATE - WV
Transmission
345.00
138.00
13.80
2
0
0.00
682
TRI-STATE - WV
Transmission
345.00
137.50
13.80
270.00
1
0
0.00
683
TULTEX - VA
Distribution
34.50
7.50
2.50
2
0
0.00
684
TULTEX - VA
Distribution
34.50
7.20
5.00
4
0
0.00
685
TURKEY PEN - VA
Distribution
69.00
12.00
10.50
1
0
0.00
686
TURNER - WV
Transmission
69.00
35.40
13.80
30.00
1
0
0.00
687
TURNER - WV
Transmission
138.00
70.50
46.00
54.00
0
1
0
0.00
688
TURNER - WV
Transmission
138.00
69.00
46.00
84.00
1
0
0.00
689
UNITED FUEL GAS COMPANY - WV
Distribution
69.00
4.00
6.25
1
0
0.00
690
UPPER BRANCH - WV
Distribution
46.00
7.20
2.01
3
0
0.00
691
URY - WV
Distribution
46.00
12.00
20.00
1
0
0.00
692
VAN - WV
Distribution
69.00
12.00
6.25
1
0
0.00
693
VETERANS HOSPITAL - VA
Distribution
34.50
4.00
10.00
2
0
0.00
694
VICKER - VA
Distribution
138.00
13.09
20.00
1
0
0.00
695
VINTON - VA
Distribution
138.00
34.50
30.00
1
0
0.00
696
VINTON - VA
Distribution
138.00
13.09
25.00
1
0
0.00
697
WALNUT AVENUE - VA
Distribution
69.00
12.00
22.40
1
0
0.00
698
WALTON PARK - VA
Distribution
69.00
2.40
2.00
1
0
0.00
699
WARD HOLLOW - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
32.40
700
WARD HOLLOW - WV
Transmission
46.00
13.80
40.00
2
0
0.00
701
WASENA - VA
Distribution
69.00
13.09
20.00
1
0
0.00
702
WASENA - VA
Distribution
69.00
12.00
20.00
1
0
0.00
703
WAYNE - WV
Distribution
34.50
13.09
10.50
1
0
0.00
704
WAYNE - WV
Distribution
34.50
12.00
5.00
1
0
0.00
705
WELCH - WV
Distribution
138.00
13.09
22.40
1
0
0.00
706
WEST BASSETT - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
28.80
707
WEST BASSETT - VA
Transmission
138.00
69.00
34.50
128.00
1
0
0.00
708
WEST BASSETT - VA
Transmission
34.50
34.50
25.00
1
0
0.00
709
WEST HUNTINGTON - WV
Transmission
138.00
69.00
34.50
130.00
1
0
0.00
710
WEST HUNTINGTON - WV
Transmission
34.50
0.00
0.00
0.00
STATCAP
1
9.60
711
WEST HUNTINGTON - WV
Transmission
138.00
13.09
9.38
1
0
0.00
712
WEST HUNTINGTON - WV
Transmission
138.00
34.50
25.00
1
0
0.00
713
WESTLAKE - VA
Distribution
138.00
34.50
60.00
2
0
0.00
714
WHARNCLIFFE - WV
Transmission
46.00
0.00
0.00
0.00
STATCAP
1
9.60
715
WHEATLAND - VA
Distribution
69.00
12.00
20.00
1
0
0.00
716
WHETSTONE BRANCH - VA
Transmission
69.00
0.00
0.00
0.00
STATCAP
1
14.39
717
WHITESTICK - WV
Distribution
46.00
12.00
22.40
1
0
0.00
718
WITT - VA
Distribution
69.00
4.36
12.50
1
0
0.00
719
WOLF GLADE - VA
Transmission
138.00
70.50
13.09
78.00
1
0
0.00
720
WOOLWINE - VA
Distribution
69.00
34.50
25.00
1
0
0.00
721
WURNO - VA
Distribution
138.00
0.00
0.00
0.00
STATCAP
1
14.40
722
WURNO - VA (A)
Distribution
138.00
34.50
30.00
1
0
0.00
723
WURNO - VA (B)
Distribution
138.00
34.50
30.00
1
0
0.00
724
WYOMING - WV
Transmission
765.00
138.00
13.80
1250.00
5
0
0.00
725
WYOMING - WV
Transmission
765.00
138.00
12.00
250.00
1
0
0.00
726
WYTHE - VA
Transmission
138.00
34.00
25.00
1
0
0.00
727
WYTHE - VA
Transmission
138.00
0.00
0.00
0.00
STATCAP
1
50.40
728
WYTHE - VA
Transmission
138.00
34.50
35.00
1
0
0.00
729
TotalTransmissionSubstationMember
8,935
730
Total
8,935


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
  1. Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies.
  2. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general".
  3. Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.
Description of the Good or Service
(a)
Name of Associated/Affiliated Company
(b)
Account(s) Charged or Credited
(c)
Amount Charged or Credited
(d)
1
Non-power Goods or Services Provided by Affiliated
2
Administrative and General Expenses - Maintenance
AEPSC
5,243,052
3
Distribution Expenses - Maintenance
AEPSC
1,513,942
4
Regulatory Services
AEPSC
1,800,779
5
Administrative and General Expenses - Operation
AEPSC
4,529,118
6
Distribution Expenses - Maintenance
I&M
529,658
7
Real Estate & Workplace Svcs
AEPSC
3,797,285
8
Audit Services
AEPSC
1,563,091
9
Distribution Expenses - Maintenance
KgPCo
933,610
10
Physical & Cyber Security
AEPSC
1,611,607
11
Bus Ops & Perf Assurance
AEPSC
1,817,542
12
Distribution Expenses - Maintenance
OPCo
1,749,030
13
Other Power Supply Expenses
AEPSC
7,073,149
14
Civil & Political Activities and Other Svcs
AEPSC
1,319,132
15
Factored AR
AEP Credit Inc.
2,406,043
16
Construction Services
AEPSC
144,023,051
17
Distribution Expenses - Operation
AEPSC
5,014,791
18
Materials and Supplies
KgPCo
586,659
19
Construction Services
I&M
729,672
20
Distribution Expenses - Operation
KgPCo
300,184
21
Barging
I&M
40,129,351
22
Construction Services
KgPCo
2,077,631
23
Environmental Services
AEPSC
836,885
24
Materials and Supplies
OPCo
6,376,213
25
Construction Services
OPCo
1,809,573
26
Urea
KPCo
964,517
27
Materials and Supplies
KPCo
251,959
28
Corp Safety & Health
AEPSC
1,812,019
29
Treasury & Risk
AEPSC
2,284,779
30
Materials and Supplies
I&M
561,541
31
Corporate Accounting
AEPSC
3,206,310
32
Transmission Expenses - Operation
AEPSC
21,375,898
33
Legal GC/Administration
AEPSC
8,423,789
34
Corporate Communications
AEPSC
1,394,259
35
Transmission Expenses - Maintenance
AEPSC
6,042,635
36
Infrastructure Ops & Support
AEPSC
1,340,290
37
Corporate Human Resources
AEPSC
4,131,452
38
Tax Services
AEPSC
1,295,235
39
Information Technology
AEPSC
11,140,939
40
Corporate Planning & Budgeting
AEPSC
2,019,177
41
Strategy & Transformation
AEPSC
1,227,454
42
Hydraulic Power Generation - Maintenance
AEPSC
994,943
43
Customer Accounts Expenses
AEPSC
16,766,026
44
Steam Power Generation - Operation
AEPSC
17,954,930
45
Hydraulic Power Generation - Operation
AEPSC
3,586,934
46
Customer Accounts Expenses
KgPCo
273,344
47
Steam Power Generation - Maintenance
AEPSC
5,674,767
48
Grid Solutions
AEPSC
1,152,480
49
Customer Service and Informational Expenses
AEPSC
418,595
50
Other Operating Revenues
OPCo
1,078,555
51
Fuel & Storeroom Services
AEPSC
11,559,394
52
Customer Support
AEPSC
2,262,305
53
Research and Other Services
AEPSC
6,590,121
54
Factored Customer A/R Bad Debts
AEP Credit Inc.
4,600,616
19
20
Non-power Goods or Services Provided for Affiliated
21
Building and Property Leases
AEPSC
3,974,794
22
Fleet and Vehicle Charges
AEPSC
4,103,749
23
Expenses of Nonutility Operations
I&M
5,016,568
24
Materials and Supplies
KPCo
310,746
25
Facility Rent
WVTCo
2,610,035
26
O&M Services for Jointly Owned Facility - Sporn
AEP Generation Resources
302,950
27
Other Operating Revenues
I&M
305,346
28
Other Operating Revenues
OPCo
923,114
29
Other Operating Revenues
PSO
341,076
30
Urea
KPCo
1,367,952
31
Use of Jointly Owned Facility
APTCo
1,963,379
32
Use of Jointly Owned Facility
WVTCo
399,449
33
Administrative and General Expenses - Maintenance
KPCo
291,189
34
Central Machine Shop
I&M
2,352,794
35
Central Machine Shop
KPCo
972,875
36
Central Machine Shop
OPCo
367,854
37
Central Machine Shop
PSO
738,638
38
Central Machine Shop
SWEPCo
2,683,567
39
Construction Services
KgPCo
924,571
40
Construction Services
KgPCo
583,838
41
Construction Services
OPCo
259,364
42
Construction Services
WPCo
648,264
43
Construction Services
WVTCo
908,736
44
Distribution Expenses - Maintenance
KgPCo
303,524
45
Distribution Expenses - Maintenance
WPCo
350,257
42


Name of Respondent:

Appalachian Power Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/19/2022
Year/Period of Report

End of:
2021
/
Q4
FOOTNOTE DATA

(a) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
Certain managerial and professional services provided by AEPSC are allocated among multiple affiliates. The costs of the services are billed on a direct-charge basis, whenever possible. Costs incurred to perform services that benefit more than one company are allocated to the benefiting companies using one of 80 FERC accepted allocation factors. The allocation factors used to bill for services performed by AEPSC are based upon formulae that consider factors such as number of customers, number of employees, number of transmission pole miles, number of invoices and other factors. The data upon which these formulae are based is updated monthly, quarterly, semi-annually or annually, depending on the particular factor and its volatility. The billings for services are made at cost and include no compensation for a return on investment.
(b) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
580, 582-584, 586, 588
(c) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
107, 108, 163, 500, 506, 512-513, 524, 530, 531, 532, 544, 920
(d) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
107, 108, 500, 506, 512, 513, 514, 920
(e) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
107, 108, 512, 513, 514, 531, 920
(f) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
107, 108, 502, 512-513, 920
(g) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
Costs related to AEP's fleet vehicles are allocated in the same manner as the labor of each department utilizing the vehicles. To the extent a department provides service to another affiliate company, an applicable share of their fleet costs are also assigned to that affiliate company.