2103102110821105062718803EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G7281281191010051121812150813211114111718611199202040521111924912252106267192727282705312217321308333193415113512103719083821939710401016411513421418435442120461614479154812024910075031451120752111852112624077200919140820613681618692903771212792913123131280512162290934171141205417111114259115140512061602241467175081109810118039301612163281852061261957051419251151572305280930514039813241181121511170815054112014125161172515200622510131916131832201113161922194291019093071705525031115180231861209707802142072019310317132810826111003418300811518909301230910124122306608410228158081010231010215144081064322151220111217103131712150772042317280617102713104210721193082610521719193172303105171490817072204629202011271032010629081042514290671011230951727091071717180530181282213906250421295053152707260810201771814241711290740222051271518091510131317033031015250514261529121110221415111807151526161619042917316171765197121905181091915409100819271119241991720281651010719182181715036072112270226042218171923210591429052206241590426171702252703121461822102627122319262020427518713270610142814122316820110291316121517202033030172002160483171621321416322402270827028193320049104141415343108815261335806131318134163619181714071112372008814190322083818194121712132039291914135022507615171718210415097807301118271612165116021021323301913055031611160416203061724091914182007181516211524102091921094201181132029151012190224162229071603603110723192026182052819242021810282012082526419221504268046208122813271913251930042428291618149162918117902270470330021714111051706160728031002181612020181303107142814291128111520709413919220928042211131930032207301320162413404120350422202817141713024403240816162904112111122165301023141907220326097111019161012131418202113311280751430142512110221171521183005250215129132020135165091018210226073103041808181514042605250822121409201609121920721415022003809210327206171910171520053006240612182405708130751326191818115512120423082315280831661304250616082403206161510172307606615100930202404131210042602300927141314111630158171627191309181161429028054152420312161225091410211416111106180620126051605230423112302191122022606141424181020110511035071013140661610325209032415280210208211611201812140281896103007111627173021104151931325177048161620102518161313111917180419062914261220202312706160623182113061704191240610061506260312112108C00118313157FalseOriginal value: N918O407261413102320905321201545678791013141609234561709910121314271515161720212513456 C001183 ferc:TransmissionStudiesMember 7-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-17 2018-01-01 2018-12-31 C001183 17-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-19 2018-01-01 2018-12-31 C001183 24-18 2018-01-01 2018-12-31 C001183 ferc:AugustMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 5-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-2 2018-01-01 2018-12-31 C001183 22-11 2018-01-01 2018-12-31 C001183 21-16 2018-01-01 2018-12-31 C001183 0-48 2018-01-01 2018-12-31 C001183 3-17 2018-01-01 2018-12-31 C001183 26-4 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 2017-12-31 C001183 ferc:TransmissionStudiesMember 22-6 2018-01-01 2018-12-31 C001183 9-17 2018-01-01 2018-12-31 C001183 0-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-13 2018-01-01 2018-12-31 C001183 0-19 2018-01-01 2018-12-31 C001183 0-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-12 2018-01-01 2018-12-31 C001183 0-36 2018-01-01 2018-12-31 C001183 7-2 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-9 2018-01-01 2018-12-31 C001183 15-13 2018-01-01 2018-12-31 C001183 16-16 2018-01-01 2018-12-31 C001183 6-17 2018-01-01 2018-12-31 C001183 2-4 2018-01-01 2018-12-31 C001183 0-5 2017-01-01 2017-12-31 C001183 0-26 2018-01-01 2018-12-31 C001183 6-18 2018-01-01 2018-12-31 C001183 30-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-19 2018-01-01 2018-12-31 C001183 13-8 2018-01-01 2018-12-31 C001183 11-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-2 2018-01-01 2018-12-31 C001183 11-19 2018-01-01 2018-12-31 C001183 0-11 2018-01-01 2018-12-31 C001183 15-19 2018-01-01 2018-12-31 C001183 0-25 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-15 2018-01-01 2018-12-31 C001183 26-9 2018-01-01 2018-12-31 C001183 0-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-9 2018-01-01 2018-12-31 C001183 31-2 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-9 2018-01-01 2018-12-31 C001183 8-4 2018-01-01 2018-12-31 C001183 18-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-20 2018-01-01 2018-12-31 C001183 1-4 2018-01-01 2018-12-31 C001183 25-4 2018-01-01 2018-12-31 C001183 11-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-13 2018-01-01 2018-12-31 C001183 0-14 2018-01-01 2018-12-31 C001183 24-4 2018-01-01 2018-12-31 C001183 0-3 2018-12-31 C001183 2-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-8 2018-01-01 2018-12-31 C001183 29-9 2018-01-01 2018-12-31 C001183 30-9 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-9 2018-12-31 C001183 ferc:ElectricUtilityMember 0-22 2018-01-01 2018-12-31 C001183 0-50 2018-01-01 2018-12-31 C001183 27-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-17 2018-01-01 2018-12-31 C001183 27-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-15 2018-01-01 2018-12-31 C001183 8-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-20 2018-01-01 2018-12-31 C001183 0-30 2018-01-01 2018-12-31 C001183 18-8 2018-01-01 2018-12-31 C001183 25-20 2018-01-01 2018-12-31 C001183 2018-01-01 2018-09-30 C001183 9-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-13 2018-01-01 2018-12-31 C001183 25-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-5 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-06-30 C001183 ferc:TransmissionStudiesMember 3-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-16 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-12-31 C001183 ScheduleOtherRegulatoryLiabilitiesAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-4 2018-01-01 2018-12-31 C001183 11-6 2018-01-01 2018-12-31 C001183 28-3 2018-01-01 2018-12-31 C001183 26-20 2018-01-01 2018-12-31 C001183 0-14 2018-01-01 2018-12-31 C001183 8-10 2018-01-01 2018-12-31 C001183 0-7 2017-01-01 2017-12-31 C001183 7-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-6 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-12-31 C001183 10-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-6 2018-01-01 2018-12-31 C001183 9-10 2018-01-01 2018-12-31 C001183 16-5 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-18 2018-01-01 2018-12-31 C001183 2-13 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-12-31 C001183 ferc:FebruaryMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-2 2018-01-01 2018-12-31 C001183 14-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-8 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-12 2018-01-01 2018-12-31 C001183 5-4 2018-01-01 2018-12-31 C001183 0-79 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-09-30 C001183 6-9 2018-01-01 2018-12-31 C001183 0-21 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-17 2018-01-01 2018-12-31 C001183 5-6 2018-01-01 2018-12-31 C001183 19-9 2018-01-01 2018-12-31 C001183 9-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-10 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-13 2018-12-31 C001183 0-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-4 2018-01-01 2018-12-31 C001183 ScheduleNuclearFuelMaterialsAbstract 2018-01-01 2018-12-31 C001183 20-9 2018-01-01 2018-12-31 C001183 ferc:NovemberMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-7 2018-01-01 2018-12-31 C001183 6-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-9 2018-01-01 2018-12-31 C001183 28-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-6 2018-01-01 2018-12-31 C001183 ScheduleElectricPropertyLeasedToOthersAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-15 2018-01-01 2018-12-31 C001183 25-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-4 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-11 2018-01-01 2018-12-31 C001183 1-1 2018-01-01 2018-12-31 C001183 0-14 2018-01-01 2018-12-31 C001183 7-5 2018-01-01 2018-12-31 C001183 14-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-20 2018-01-01 2018-12-31 C001183 24-6 2018-01-01 2018-12-31 C001183 ScheduleInvestmentsInSubsidiaryCompaniesAbstract 2018-01-01 2018-12-31 C001183 22-18 2018-01-01 2018-12-31 C001183 29-20 2018-01-01 2018-12-31 C001183 18-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-10 2018-01-01 2018-12-31 C001183 30-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-8 2018-01-01 2018-12-31 C001183 11-4 2018-01-01 2018-12-31 C001183 13-15 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-22 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-3 2018-01-01 2018-12-31 C001183 1-15 2018-01-01 2018-12-31 C001183 0-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-3 2018-01-01 2018-12-31 C001183 0-47 2018-01-01 2018-12-31 C001183 0-2 2018-01-01 2018-12-31 C001183 0-2 2018-01-01 2018-12-31 C001183 16-11 2018-01-01 2018-12-31 C001183 9-16 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-11 2018-12-31 C001183 0-16 2018-01-01 2018-12-31 C001183 0-41 2018-01-01 2018-12-31 C001183 20-6 2018-01-01 2018-12-31 C001183 26-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-19 2018-01-01 2018-12-31 C001183 24-8 2018-01-01 2018-12-31 C001183 29-17 2018-01-01 2018-12-31 C001183 0-18 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-8 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-2 2018-01-01 2018-12-31 C001183 1-9 2018-01-01 2018-12-31 C001183 8-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-15 2018-01-01 2018-12-31 C001183 11-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-14 2018-01-01 2018-12-31 C001183 2-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-2 2018-01-01 2018-12-31 C001183 SchedulePurchasesSalesOfAncillaryServicesAbstract 2018-01-01 2018-12-31 C001183 0-8 2018-01-01 2018-09-30 C001183 ferc:TransmissionStudiesMember 11-13 2018-01-01 2018-12-31 C001183 13-2 2018-01-01 2018-12-31 C001183 22-19 2018-01-01 2018-12-31 C001183 0-51 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-16 2018-01-01 2018-12-31 C001183 12-13 2018-01-01 2018-12-31 C001183 23-15 2018-01-01 2018-12-31 C001183 22-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-20 2018-01-01 2018-12-31 C001183 8-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-12 2018-01-01 2018-12-31 C001183 28-9 2018-01-01 2018-12-31 C001183 29-2 2018-01-01 2018-12-31 C001183 21-2 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-12-31 C001183 0-38 2018-01-01 2018-12-31 C001183 1-2 2018-01-01 2018-12-31 C001183 30-18 2018-01-01 2018-12-31 C001183 1-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-5 2018-01-01 2018-12-31 C001183 23-5 2018-01-01 2018-12-31 C001183 6-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-11 2018-01-01 2018-12-31 C001183 21-13 2018-01-01 2018-12-31 C001183 7-18 2018-01-01 2018-12-31 C001183 0-79 2017-01-01 2017-12-31 C001183 23-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-11 2018-01-01 2018-12-31 C001183 17-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-12 2018-01-01 2018-12-31 C001183 23-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 31-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-18 2018-01-01 2018-12-31 C001183 16-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-14 2018-01-01 2018-12-31 C001183 23-7 2018-01-01 2018-12-31 C001183 1-20 2018-01-01 2018-12-31 C001183 16-15 2018-01-01 2018-12-31 C001183 2-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-17 2018-01-01 2018-12-31 C001183 0-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-12 2018-01-01 2018-12-31 C001183 23-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-13 2018-01-01 2018-12-31 C001183 ferc:ElectricPlantInServiceMember ferc:ElectricUtilityMember 2018-12-31 C001183 20-14 2018-01-01 2018-12-31 C001183 ScheduleCapitalStockAbstract 2018-01-01 2018-12-31 C001183 24-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-10 2018-01-01 2018-12-31 C001183 0-69 2017-01-01 2017-12-31 C001183 ferc:ElectricUtilityMember 2018-01-01 2018-12-31 C001183 19-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-3 2018-01-01 2018-12-31 C001183 10-8 2018-01-01 2018-12-31 C001183 2-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-4 2018-01-01 2018-12-31 C001183 0-27 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-18 2018-01-01 2018-12-31 C001183 14-2 2018-01-01 2018-12-31 C001183 0-20 2017-01-01 2017-12-31 C001183 ferc:TransmissionStudiesMember 26-12 2018-01-01 2018-12-31 C001183 14-10 2018-01-01 2018-12-31 C001183 4-2 2018-01-01 2018-12-31 C001183 29-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-8 2018-01-01 2018-12-31 C001183 5-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-9 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-12-31 C001183 24-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-11 2018-01-01 2018-12-31 C001183 ScheduleSalesForResaleAbstract 2018-01-01 2018-12-31 C001183 10-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-15 2018-01-01 2018-12-31 C001183 11-12 2018-01-01 2018-12-31 C001183 13-7 2018-01-01 2018-12-31 C001183 2-19 2018-01-01 2018-12-31 C001183 0-77 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-2 2018-01-01 2018-12-31 C001183 21-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-12 2018-01-01 2018-12-31 C001183 0-10 2018-01-01 2018-12-31 C001183 6-19 2018-01-01 2018-12-31 C001183 ScheduleCapitalStockExpenseAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-7 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-17 2018-12-31 C001183 15-15 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-12-31 C001183 1-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-16 2018-01-01 2018-12-31 C001183 0-23 2018-01-01 2018-12-31 C001183 4-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-14 2018-01-01 2018-12-31 C001183 0-16 2018-01-01 2018-12-31 C001183 0-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-20 2018-01-01 2018-12-31 C001183 28-13 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-12-31 C001183 19-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-13 2018-01-01 2018-12-31 C001183 0-2 2018-01-01 2018-12-31 C001183 3-19 2018-01-01 2018-12-31 C001183 0-6 2017-01-01 2017-12-31 C001183 ferc:MarchMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-19 2018-01-01 2018-12-31 C001183 10-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-11 2018-01-01 2018-12-31 C001183 18-15 2018-01-01 2018-12-31 C001183 15-14 2018-01-01 2018-12-31 C001183 10-13 2018-01-01 2018-12-31 C001183 29-14 2018-01-01 2018-12-31 C001183 30-16 2018-01-01 2018-12-31 C001183 0-17 2018-01-01 2018-12-31 C001183 0-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-13 2018-01-01 2018-12-31 C001183 16-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-13 2018-01-01 2018-12-31 C001183 16-8 2018-01-01 2018-12-31 C001183 0-68 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-12 2018-01-01 2018-12-31 C001183 23-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-7 2018-01-01 2018-12-31 C001183 0-1 2018-12-31 C001183 4-13 2018-01-01 2018-12-31 C001183 0-24 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-11 2018-01-01 2018-12-31 C001183 21-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-17 2018-01-01 2018-12-31 C001183 8-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-7 2018-01-01 2018-12-31 C001183 28-18 2018-01-01 2018-12-31 C001183 4-18 2018-01-01 2018-12-31 C001183 ferc:Quarter1Member EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 0-27 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-12 2018-01-01 2018-12-31 C001183 0-8 2018-01-01 2018-03-31 C001183 ferc:TransmissionStudiesMember 16-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-6 2018-01-01 2018-12-31 C001183 0-42 2018-01-01 2018-12-31 C001183 8-18 2018-01-01 2018-12-31 C001183 17-18 2018-01-01 2018-12-31 C001183 11-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-17 2018-01-01 2018-12-31 C001183 22-4 2018-01-01 2018-12-31 C001183 8-15 2018-01-01 2018-12-31 C001183 ferc:Quarter3Member EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 ScheduleTransmissionLinesAddedAbstract 2018-01-01 2018-12-31 C001183 9-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-15 2018-01-01 2018-12-31 C001183 5-12 2018-01-01 2018-12-31 C001183 8-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-17 2018-01-01 2018-12-31 C001183 21-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-13 2018-01-01 2018-12-31 C001183 30-6 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-10 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-17 2018-01-01 2018-12-31 C001183 0-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-4 2018-01-01 2018-12-31 C001183 1-16 2018-01-01 2018-12-31 C001183 0-7 2018-01-01 2018-12-31 C001183 3-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-3 2018-01-01 2018-12-31 C001183 0-15 2018-01-01 2018-12-31 C001183 4-7 2018-01-01 2018-12-31 C001183 17-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-9 2018-01-01 2018-12-31 C001183 11-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-5 2018-01-01 2018-12-31 C001183 27-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-13 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-12 2018-12-31 C001183 13-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-16 2018-01-01 2018-12-31 C001183 4-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-2 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-12-31 C001183 28-15 2018-01-01 2018-12-31 C001183 4-8 2018-01-01 2018-12-31 C001183 20-20 2018-01-01 2018-12-31 C001183 6-4 2018-01-01 2018-12-31 C001183 ScheduleSubstationsAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-2 2018-01-01 2018-12-31 C001183 24-20 2018-01-01 2018-12-31 C001183 0-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-2 2018-01-01 2018-12-31 C001183 7-11 2018-01-01 2018-12-31 C001183 ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract 2018-01-01 2018-12-31 C001183 4-12 2018-01-01 2018-12-31 C001183 28-10 2018-01-01 2018-12-31 C001183 17-10 2018-01-01 2018-12-31 C001183 6-5 2018-01-01 2018-12-31 C001183 17-16 2018-01-01 2018-12-31 C001183 5-15 2018-01-01 2018-12-31 C001183 21-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-13 2018-01-01 2018-12-31 C001183 9-4 2018-01-01 2018-12-31 C001183 12-11 2018-01-01 2018-12-31 C001183 ScheduleOtherPaidInCapitalAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-19 2018-01-01 2018-12-31 C001183 0-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-16 2018-01-01 2018-12-31 C001183 1-2 2018-01-01 2018-12-31 C001183 0-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-2 2018-01-01 2018-12-31 C001183 6-7 2018-01-01 2018-12-31 C001183 11-18 2018-01-01 2018-12-31 C001183 29-18 2018-01-01 2018-12-31 C001183 ferc:AprilMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 2-16 2018-01-01 2018-12-31 C001183 13-5 2018-01-01 2018-12-31 C001183 17-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-15 2018-01-01 2018-12-31 C001183 EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-9 2018-01-01 2018-12-31 C001183 27-20 2018-01-01 2018-12-31 C001183 24-7 2018-01-01 2018-12-31 C001183 26-19 2018-01-01 2018-12-31 C001183 26-5 2018-01-01 2018-12-31 C001183 27-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-13 2018-01-01 2018-12-31 C001183 30-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-17 2018-01-01 2018-12-31 C001183 18-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-3 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-25 2018-12-31 C001183 10-11 2018-01-01 2018-12-31 C001183 0-31 2018-01-01 2018-12-31 C001183 19-8 2018-01-01 2018-12-31 C001183 1-4 2018-01-01 2018-12-31 C001183 24-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-3 2018-01-01 2018-12-31 C001183 1-14 2018-01-01 2018-12-31 C001183 3-16 2018-01-01 2018-12-31 C001183 0-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-18 2018-01-01 2018-12-31 C001183 17-15 2018-01-01 2018-12-31 C001183 8-9 2018-01-01 2018-12-31 C001183 0-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-4 2018-01-01 2018-12-31 C001183 4-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-17 2018-01-01 2018-12-31 C001183 11-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-3 2018-01-01 2018-12-31 C001183 0-3 2017-12-31 C001183 0-18 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-12-31 C001183 9-13 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-18 2018-12-31 C001183 13-6 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-7 2018-01-01 2018-12-31 C001183 0-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-16 2018-01-01 2018-12-31 C001183 14-15 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-8 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-15 2018-01-01 2018-12-31 C001183 ScheduleHydroelectricGeneratingPlantStatisticsAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-4 2018-01-01 2018-12-31 C001183 ScheduleMaterialsAndSuppliesAbstract 2018-01-01 2018-12-31 C001183 12-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-2 2018-01-01 2018-12-31 C001183 16-18 2018-01-01 2018-12-31 C001183 22-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-14 2018-01-01 2018-12-31 C001183 14-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-7 2018-01-01 2018-12-31 C001183 20-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-4 2018-01-01 2018-12-31 C001183 21-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-15 2018-01-01 2018-12-31 C001183 0-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-5 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-27 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-3 2018-01-01 2018-12-31 C001183 0-2 2018-12-31 C001183 28-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-10 2018-01-01 2018-12-31 C001183 8-5 2018-01-01 2018-12-31 C001183 17-5 2018-01-01 2018-12-31 C001183 15-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-11 2018-01-01 2018-12-31 C001183 10-6 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-06-30 C001183 30-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-20 2018-01-01 2018-12-31 C001183 24-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-8 2018-01-01 2018-12-31 C001183 0-25 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-15 2018-01-01 2018-12-31 C001183 0-40 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-15 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-06-30 C001183 ferc:TransmissionStudiesMember 0-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-20 2018-01-01 2018-12-31 C001183 ScheduleGeneratingPlantStatisticsAbstract 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-12-31 C001183 9-15 2018-01-01 2018-12-31 C001183 0-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-3 2018-01-01 2018-12-31 C001183 0-2 2018-01-01 2018-06-30 C001183 0-5 2018-01-01 2018-06-30 C001183 6-20 2018-01-01 2018-12-31 C001183 19-15 2018-01-01 2018-12-31 C001183 19-5 2018-01-01 2018-12-31 C001183 15-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-12 2018-01-01 2018-12-31 C001183 0-16 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-15 2018-01-01 2018-12-31 C001183 27-8 2018-01-01 2018-12-31 C001183 15-10 2018-01-01 2018-12-31 C001183 11-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-15 2018-01-01 2018-12-31 C001183 19-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-14 2018-01-01 2018-12-31 C001183 ferc:MayMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 0-4 2017-01-01 2017-12-31 C001183 ferc:ElectricUtilityMember 0-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-20 2018-01-01 2018-12-31 C001183 0-22 2018-01-01 2018-12-31 C001183 25-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-8 2018-01-01 2018-12-31 C001183 9-7 2018-01-01 2018-12-31 C001183 24-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-17 2018-01-01 2018-12-31 C001183 26-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-20 2018-01-01 2018-12-31 C001183 0-23 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-10 2018-01-01 2018-12-31 C001183 23-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-3 2018-01-01 2018-12-31 C001183 3-9 2018-01-01 2018-12-31 C001183 3-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-11 2018-01-01 2018-12-31 C001183 18-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-19 2018-01-01 2018-12-31 C001183 13-11 2018-01-01 2018-12-31 C001183 14-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-19 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-26 2018-12-31 C001183 19-4 2018-01-01 2018-12-31 C001183 28-11 2018-01-01 2018-12-31 C001183 22-10 2018-01-01 2018-12-31 C001183 0-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-20 2018-01-01 2018-12-31 C001183 2-12 2018-01-01 2018-12-31 C001183 6-13 2018-01-01 2018-12-31 C001183 6-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-15 2018-01-01 2018-12-31 C001183 0-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-20 2018-01-01 2018-12-31 C001183 ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-4 2018-01-01 2018-12-31 C001183 18-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-16 2018-01-01 2018-12-31 C001183 0-35 2018-01-01 2018-12-31 C001183 7-17 2018-01-01 2018-12-31 C001183 29-16 2018-01-01 2018-12-31 C001183 0-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-6 2018-01-01 2018-12-31 C001183 9-20 2018-01-01 2018-12-31 C001183 26-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-9 2018-01-01 2018-12-31 C001183 20-18 2018-01-01 2018-12-31 C001183 15-20 2018-01-01 2018-12-31 C001183 0-20 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-12-31 C001183 0-17 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-12-31 C001183 9-19 2018-01-01 2018-12-31 C001183 7-7 2018-01-01 2018-12-31 C001183 9-6 2018-01-01 2018-12-31 C001183 2017-01-01 2017-12-31 C001183 ScheduleSalesOfElectricityByRateSchedulesAbstract 2018-01-01 2018-12-31 C001183 0-34 2018-01-01 2018-12-31 C001183 18-19 2018-01-01 2018-12-31 C001183 15-9 2018-01-01 2018-12-31 C001183 0-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-2 2018-01-01 2018-12-31 C001183 29-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-7 2018-01-01 2018-12-31 C001183 0-34 2018-01-01 2018-12-31 C001183 1-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-17 2018-01-01 2018-12-31 C001183 16-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-13 2018-01-01 2018-12-31 C001183 7-3 2018-01-01 2018-12-31 C001183 0-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-9 2018-01-01 2018-12-31 C001183 22-12 2018-01-01 2018-12-31 C001183 ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract 2018-01-01 2018-12-31 C001183 1-8 2018-01-01 2018-12-31 C001183 ScheduleTransmissionOfElectricityForOthersAbstract 2018-01-01 2018-12-31 C001183 19-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-14 2018-01-01 2018-12-31 C001183 4-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-8 2018-01-01 2018-12-31 C001183 6-12 2018-01-01 2018-12-31 C001183 8-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-15 2018-01-01 2018-12-31 C001183 1-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-5 2018-01-01 2018-12-31 C001183 12-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-6 2018-01-01 2018-12-31 C001183 4-17 2018-01-01 2018-12-31 C001183 20-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-11 2018-01-01 2018-12-31 C001183 14-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-19 2018-01-01 2018-12-31 C001183 5-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-10 2018-01-01 2018-12-31 C001183 12-14 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-03-31 C001183 0-33 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-15 2018-01-01 2018-12-31 C001183 0-9 2018-01-01 2018-12-31 C001183 ferc:DecemberMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-20 2018-01-01 2018-12-31 C001183 17-13 2018-01-01 2018-12-31 C001183 27-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-8 2018-01-01 2018-12-31 C001183 24-11 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-25 2018-01-01 2018-12-31 C001183 0-12 2018-01-01 2018-12-31 C001183 0-7 2018-01-01 2018-03-31 C001183 0-68 2017-01-01 2017-12-31 C001183 ferc:TransmissionStudiesMember 24-15 2018-01-01 2018-12-31 C001183 0-37 2018-01-01 2018-12-31 C001183 ferc:Quarter2Member EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 12-16 2018-01-01 2018-12-31 C001183 19-18 2018-01-01 2018-12-31 C001183 22-13 2018-01-01 2018-12-31 C001183 7-6 2018-01-01 2018-12-31 C001183 28-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-19 2018-01-01 2018-12-31 C001183 0-9 2017-12-31 C001183 ferc:ElectricUtilityMember 0-14 2018-01-01 2018-12-31 C001183 20-5 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-12-31 C001183 3-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-8 2018-01-01 2018-12-31 C001183 22-17 2018-01-01 2018-12-31 C001183 0-1 2017-12-31 C001183 ferc:TransmissionStudiesMember 30-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-10 2018-01-01 2018-12-31 C001183 30-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-10 2018-01-01 2018-12-31 C001183 27-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-19 2018-01-01 2018-12-31 C001183 ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-12-31 C001183 7-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-20 2018-01-01 2018-12-31 C001183 ferc:ElectricPlantInServiceMember ferc:ElectricUtilityMember 2017-12-31 C001183 27-14 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-20 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-14 2018-01-01 2018-12-31 C001183 14-20 2018-01-01 2018-12-31 C001183 18-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-13 2018-01-01 2018-12-31 C001183 1-19 2018-01-01 2018-12-31 C001183 12-12 2018-01-01 2018-12-31 C001183 11-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-13 2018-01-01 2018-12-31 C001183 0-9 2018-01-01 2018-12-31 C001183 29-4 2018-01-01 2018-12-31 C001183 28-12 2018-01-01 2018-12-31 C001183 19-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-10 2018-01-01 2018-12-31 C001183 29-12 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-03-31 C001183 10-16 2018-01-01 2018-12-31 C001183 25-17 2018-01-01 2018-12-31 C001183 ScheduleTransmissionOfElectricityByOthersAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-5 2018-01-01 2018-12-31 C001183 12-7 2018-01-01 2018-12-31 C001183 10-2 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-12-31 C001183 ScheduleCommonUtilityPlantAndExpensesAbstract 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-24 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-11 2018-01-01 2018-12-31 C001183 0-21 2018-01-01 2018-12-31 C001183 26-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-8 2018-01-01 2018-12-31 C001183 12-3 2018-01-01 2018-12-31 C001183 0-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-7 2018-01-01 2018-12-31 C001183 24-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-4 2018-01-01 2018-12-31 C001183 ScheduleSteamElectricGeneratingPlantStatisticsAbstract 2018-01-01 2018-12-31 C001183 18-14 2018-01-01 2018-12-31 C001183 ferc:Quarter4Member EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-17 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-12-31 C001183 19-2 2018-01-01 2018-12-31 C001183 7-8 2018-01-01 2018-12-31 C001183 23-6 2018-01-01 2018-12-31 C001183 27-2 2018-01-01 2018-12-31 C001183 0-22 2018-01-01 2018-12-31 C001183 0-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-19 2018-01-01 2018-12-31 C001183 18-5 2018-01-01 2018-12-31 C001183 12-20 2018-01-01 2018-12-31 C001183 6-15 2018-01-01 2018-12-31 C001183 27-9 2018-01-01 2018-12-31 C001183 0-1 2017-12-31 C001183 30-2 2018-01-01 2018-12-31 C001183 2017-12-31 C001183 23-14 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-1 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-3 2018-01-01 2018-12-31 C001183 30-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-10 2018-01-01 2018-12-31 C001183 0-35 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-6 2018-01-01 2018-12-31 C001183 30-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-3 2018-01-01 2018-12-31 C001183 0-38 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-17 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-5 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-6 2018-01-01 2018-12-31 C001183 30-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-14 2018-01-01 2018-12-31 C001183 ferc:OctoberMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 27-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-2 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-9 2018-01-01 2018-12-31 C001183 0-8 2018-01-01 2018-12-31 C001183 1-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-10 2018-01-01 2018-12-31 C001183 4-10 2018-01-01 2018-12-31 C001183 ferc:JuneMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 25-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-11 2018-01-01 2018-12-31 C001183 3-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-10 2018-01-01 2018-12-31 C001183 23-9 2018-01-01 2018-12-31 C001183 11-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-12 2018-01-01 2018-12-31 C001183 16-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-16 2018-01-01 2018-12-31 C001183 15-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-4 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-27 2018-01-01 2018-12-31 C001183 29-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-20 2018-01-01 2018-12-31 C001183 0-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-14 2018-01-01 2018-12-31 C001183 0-29 2018-01-01 2018-12-31 C001183 11-15 2018-01-01 2018-12-31 C001183 5-10 2018-01-01 2018-12-31 C001183 0-32 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-19 2018-01-01 2018-12-31 C001183 10-20 2018-01-01 2018-12-31 C001183 12-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-17 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-15 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-7 2018-01-01 2018-12-31 C001183 12-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-15 2018-01-01 2018-12-31 C001183 3-13 2018-01-01 2018-12-31 C001183 0-19 2018-01-01 2018-12-31 C001183 5-7 2018-01-01 2018-12-31 C001183 1-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-13 2018-01-01 2018-12-31 C001183 2-18 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-09-30 C001183 ferc:TransmissionStudiesMember 14-14 2018-01-01 2018-12-31 C001183 10-9 2018-01-01 2018-12-31 C001183 2018-01-01 2018-06-30 C001183 ferc:TransmissionStudiesMember 21-3 2018-01-01 2018-12-31 C001183 14-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-10 2018-01-01 2018-12-31 C001183 2016-12-31 C001183 29-6 2018-01-01 2018-12-31 C001183 0-44 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-5 2018-01-01 2018-12-31 C001183 14-12 2018-01-01 2018-12-31 C001183 0-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-9 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-7 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 2017-01-01 2017-12-31 C001183 0-28 2018-01-01 2018-12-31 C001183 1-10 2018-01-01 2018-12-31 C001183 20-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-4 2018-01-01 2018-12-31 C001183 0-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-7 2018-01-01 2018-12-31 C001183 6-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-6 2018-01-01 2018-12-31 C001183 15-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-18 2018-01-01 2018-12-31 C001183 29-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-9 2018-01-01 2018-12-31 C001183 12-5 2018-01-01 2018-12-31 C001183 21-4 2018-01-01 2018-12-31 C001183 23-3 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-14 2018-12-31 C001183 29-3 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 2018-12-31 C001183 16-20 2018-01-01 2018-12-31 C001183 6-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-16 2018-01-01 2018-12-31 C001183 17-12 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-3 2018-12-31 C001183 0-1 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-6 2018-01-01 2018-12-31 C001183 8-20 2018-01-01 2018-12-31 C001183 0-37 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-9 2018-01-01 2018-12-31 C001183 5-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-8 2018-01-01 2018-12-31 C001183 0-13 2018-01-01 2018-12-31 C001183 30-11 2018-01-01 2018-12-31 C001183 0-10 2018-01-01 2018-12-31 C001183 5-18 2018-01-01 2018-12-31 C001183 7-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-8 2018-01-01 2018-12-31 C001183 0-26 2018-01-01 2018-12-31 C001183 23-8 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-12-31 C001183 21-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-11 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-16 2018-12-31 C001183 30-19 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-17 2018-01-01 2018-12-31 C001183 14-3 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-12-31 C001183 5-17 2018-01-01 2018-12-31 C001183 16-2 2018-01-01 2018-12-31 C001183 20-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-3 2018-01-01 2018-12-31 C001183 6-8 2018-01-01 2018-12-31 C001183 ferc:DirectPayrollDistributionMember 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-2 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-18 2018-01-01 2018-12-31 C001183 0-13 2018-01-01 2018-12-31 C001183 22-6 2018-01-01 2018-12-31 C001183 12-18 2018-01-01 2018-12-31 C001183 0-24 2018-01-01 2018-12-31 C001183 7-16 2018-01-01 2018-12-31 C001183 27-12 2018-01-01 2018-12-31 C001183 28-16 2018-01-01 2018-12-31 C001183 ScheduleElectricPlantHeldForFutureUseAbstract 2018-01-01 2018-12-31 C001183 26-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-6 2018-01-01 2018-12-31 C001183 0-46 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-7 2018-01-01 2018-12-31 C001183 0-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-4 2018-01-01 2018-12-31 C001183 9-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-16 2018-01-01 2018-12-31 C001183 ferc:RegionalTransmissionAndMarketOperationMember ferc:ElectricUtilityMember 2018-01-01 2018-12-31 C001183 4-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-11 2018-01-01 2018-12-31 C001183 22-3 2018-01-01 2018-12-31 C001183 12-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-20 2018-01-01 2018-12-31 C001183 0-18 2018-01-01 2018-12-31 C001183 18-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-3 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-12-31 C001183 21-8 2018-01-01 2018-12-31 C001183 1-5 2018-01-01 2018-12-31 C001183 16-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-4 2018-01-01 2018-12-31 C001183 0-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-17 2018-01-01 2018-12-31 C001183 1-13 2018-01-01 2018-12-31 C001183 0-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-17 2018-01-01 2018-12-31 C001183 17-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-9 2018-01-01 2018-12-31 C001183 6-6 2018-01-01 2018-12-31 C001183 28-4 2018-01-01 2018-12-31 C001183 26-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-16 2018-01-01 2018-12-31 C001183 19-10 2018-01-01 2018-12-31 C001183 0-1 2018-12-31 C001183 0-31 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-16 2018-01-01 2018-12-31 C001183 29-15 2018-01-01 2018-12-31 C001183 0-19 2017-01-01 2017-12-31 C001183 19-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-13 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 31-3 2018-01-01 2018-12-31 C001183 9-11 2018-01-01 2018-12-31 C001183 15-12 2018-01-01 2018-12-31 C001183 ScheduleElectricEnergyAccountAbstract 2018-01-01 2018-12-31 C001183 22-16 2018-01-01 2018-12-31 C001183 0-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-5 2018-01-01 2018-12-31 C001183 5-2 2018-01-01 2018-12-31 C001183 15-3 2018-01-01 2018-12-31 C001183 13-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-19 2018-01-01 2018-12-31 C001183 14-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-18 2018-01-01 2018-12-31 C001183 21-15 2018-01-01 2018-12-31 C001183 ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract 2018-01-01 2018-12-31 C001183 10-10 2018-01-01 2018-12-31 C001183 22-14 2018-01-01 2018-12-31 C001183 0-17 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-12-31 C001183 21-17 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-12-31 C001183 8-16 2018-01-01 2018-12-31 C001183 4-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-4 2018-01-01 2018-12-31 C001183 24-3 2018-01-01 2018-12-31 C001183 17-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-19 2018-01-01 2018-12-31 C001183 1-3 2018-01-01 2018-12-31 C001183 0-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-17 2018-01-01 2018-12-31 C001183 25-14 2018-01-01 2018-12-31 C001183 0-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-16 2018-01-01 2018-12-31 C001183 ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-10 2018-01-01 2018-12-31 C001183 0-25 2018-01-01 2018-12-31 C001183 0-27 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-9 2018-01-01 2018-12-31 C001183 24-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-18 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-26 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-6 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-14 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-23 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-9 2018-01-01 2018-12-31 C001183 3-12 2018-01-01 2018-12-31 C001183 20-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-20 2018-01-01 2018-12-31 C001183 10-17 2018-01-01 2018-12-31 C001183 0-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-17 2018-01-01 2018-12-31 C001183 4-5 2018-01-01 2018-12-31 C001183 20-3 2018-01-01 2018-12-31 C001183 23-2 2018-01-01 2018-12-31 C001183 0-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-17 2018-01-01 2018-12-31 C001183 0-26 2018-01-01 2018-12-31 C001183 2018-12-31 C001183 ferc:ElectricUtilityMember 0-19 2018-12-31 C001183 20-19 2018-01-01 2018-12-31 C001183 3-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-5 2018-01-01 2018-12-31 C001183 28-8 2018-01-01 2018-12-31 C001183 15-4 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-12-31 C001183 0-8 2018-01-01 2018-06-30 C001183 ferc:TransmissionStudiesMember 12-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-17 2018-01-01 2018-12-31 C001183 15-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-2 2018-01-01 2018-12-31 C001183 15-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-8 2018-01-01 2018-12-31 C001183 0-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-6 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-12-31 C001183 10-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-4 2018-01-01 2018-12-31 C001183 0-22 2018-01-01 2018-12-31 C001183 29-19 2018-01-01 2018-12-31 C001183 2-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-7 2018-01-01 2018-12-31 C001183 26-10 2018-01-01 2018-12-31 C001183 3-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-11 2018-01-01 2018-12-31 C001183 20-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-5 2018-01-01 2018-12-31 C001183 27-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-10 2018-01-01 2018-12-31 C001183 0-2 2017-12-31 C001183 25-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-12 2018-01-01 2018-12-31 C001183 ScheduleExtraordinaryPropertyLossesAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-19 2018-01-01 2018-12-31 C001183 0-12 2018-01-01 2018-12-31 C001183 18-10 2018-01-01 2018-12-31 C001183 27-16 2018-01-01 2018-12-31 C001183 ScheduleAccumulatedDeferredIncomeTaxesAbstract 2018-01-01 2018-12-31 C001183 21-5 2018-01-01 2018-12-31 C001183 17-11 2018-01-01 2018-12-31 C001183 19-14 2018-01-01 2018-12-31 C001183 ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract 2018-01-01 2018-12-31 C001183 ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-8 2018-01-01 2018-12-31 C001183 29-10 2018-01-01 2018-12-31 C001183 10-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-16 2018-01-01 2018-12-31 C001183 8-6 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-06-30 C001183 0-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-2 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-21 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-14 2018-01-01 2018-12-31 C001183 7-4 2018-01-01 2018-12-31 C001183 0-7 2018-01-01 2018-06-30 C001183 ferc:TransmissionStudiesMember 3-18 2018-01-01 2018-12-31 C001183 27-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-10 2018-01-01 2018-12-31 C001183 0-2 2018-01-01 2018-03-31 C001183 ferc:TransmissionStudiesMember 9-6 2018-01-01 2018-12-31 C001183 17-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-6 2018-01-01 2018-12-31 C001183 0-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-11 2018-01-01 2018-12-31 C001183 0-28 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-20 2018-01-01 2018-12-31 C001183 0-39 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-14 2018-01-01 2018-12-31 C001183 19-6 2018-01-01 2018-12-31 C001183 14-17 2018-01-01 2018-12-31 C001183 26-14 2018-01-01 2018-12-31 C001183 21-18 2018-01-01 2018-12-31 C001183 5-14 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-16 2018-01-01 2018-12-31 C001183 3-8 2018-01-01 2018-12-31 C001183 3-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-14 2018-01-01 2018-12-31 C001183 0-7 2018-01-01 2018-12-31 C001183 2018-01-01 2018-03-31 C001183 2-10 2018-01-01 2018-12-31 C001183 4-14 2018-01-01 2018-12-31 C001183 23-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-5 2018-01-01 2018-12-31 C001183 13-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-5 2018-01-01 2018-12-31 C001183 0-14 2018-01-01 2018-12-31 C001183 4-20 2018-01-01 2018-12-31 C001183 23-12 2018-01-01 2018-12-31 C001183 28-6 2018-01-01 2018-12-31 C001183 3-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-7 2018-01-01 2018-12-31 C001183 13-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-10 2018-01-01 2018-12-31 C001183 17-8 2018-01-01 2018-12-31 C001183 13-18 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-21 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-7 2018-01-01 2018-12-31 C001183 26-8 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-09-30 C001183 ferc:TransmissionStudiesMember 16-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-18 2018-01-01 2018-12-31 C001183 7-10 2018-01-01 2018-12-31 C001183 ferc:SeptemberMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 0-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-14 2018-01-01 2018-12-31 C001183 22-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-16 2018-01-01 2018-12-31 C001183 0-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-2 2018-01-01 2018-12-31 C001183 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-20 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-3 2018-01-01 2018-12-31 C001183 22-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-13 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-03-31 C001183 ferc:TransmissionStudiesMember 2-18 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-3 2018-01-01 2018-12-31 C001183 0-2 2018-01-01 2018-09-30 C001183 12-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-8 2018-01-01 2018-12-31 C001183 5-9 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-3 2018-01-01 2018-12-31 C001183 5-20 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-09-30 C001183 14-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-8 2018-01-01 2018-12-31 C001183 18-13 2018-01-01 2018-12-31 C001183 4-9 2018-01-01 2018-12-31 C001183 8-14 2018-01-01 2018-12-31 C001183 14-18 2018-01-01 2018-12-31 C001183 5-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-5 2018-01-01 2018-12-31 C001183 0-12 2018-01-01 2018-12-31 C001183 26-18 2018-01-01 2018-12-31 C001183 11-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 18-11 2018-01-01 2018-12-31 C001183 0-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-4 2018-01-01 2018-12-31 C001183 26-17 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-12-31 C001183 0-24 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-23 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-7 2018-01-01 2018-12-31 C001183 0-39 2018-01-01 2018-12-31 C001183 ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract 2018-01-01 2018-12-31 C001183 12-6 2018-01-01 2018-12-31 C001183 0-8 2018-01-01 2018-12-31 C001183 17-2 2018-01-01 2018-12-31 C001183 20-10 2018-01-01 2018-12-31 C001183 2-11 2018-01-01 2018-12-31 C001183 0-4 2018-12-31 C001183 25-11 2018-01-01 2018-12-31 C001183 19-12 2018-01-01 2018-12-31 C001183 24-15 2018-01-01 2018-12-31 C001183 22-15 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-12-31 C001183 13-10 2018-01-01 2018-12-31 C001183 0-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-20 2018-01-01 2018-12-31 C001183 8-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-2 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-11 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-03-31 C001183 30-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-2 2018-01-01 2018-12-31 C001183 15-7 2018-01-01 2018-12-31 C001183 17-4 2018-01-01 2018-12-31 C001183 0-21 2018-01-01 2018-12-31 C001183 18-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-20 2018-01-01 2018-12-31 C001183 25-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-5 2018-01-01 2018-12-31 C001183 0-1 2018-12-31 C001183 24-5 2018-01-01 2018-12-31 C001183 0-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-3 2018-01-01 2018-12-31 C001183 3-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-13 2018-01-01 2018-12-31 C001183 11-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 7-13 2018-01-01 2018-12-31 C001183 0-8 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-19 2018-01-01 2018-12-31 C001183 25-8 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-1 2018-12-31 C001183 ScheduleCorporationsControlledByRespondentAbstract 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-7 2018-01-01 2018-12-31 C001183 2-5 2018-01-01 2018-12-31 C001183 0-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-11 2018-01-01 2018-12-31 C001183 16-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-16 2018-01-01 2018-12-31 C001183 0-7 2018-01-01 2018-09-30 C001183 ferc:TransmissionStudiesMember 2-5 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-12 2018-01-01 2018-12-31 C001183 0-12 2018-01-01 2018-12-31 C001183 8-3 2018-01-01 2018-12-31 C001183 30-17 2018-01-01 2018-12-31 C001183 2-2 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-17 2018-01-01 2018-12-31 C001183 27-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-14 2018-01-01 2018-12-31 C001183 13-12 2018-01-01 2018-12-31 C001183 28-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-12 2018-01-01 2018-12-31 C001183 0-11 2018-12-31 C001183 8-11 2018-01-01 2018-12-31 C001183 0-24 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-3 2018-01-01 2018-12-31 C001183 0-17 2018-01-01 2018-12-31 C001183 20-2 2018-01-01 2018-12-31 C001183 1-11 2018-01-01 2018-12-31 C001183 13-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-20 2018-01-01 2018-12-31 C001183 9-3 2018-01-01 2018-12-31 C001183 26-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-15 2018-01-01 2018-12-31 C001183 25-15 2018-01-01 2018-12-31 C001183 15-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-14 2018-01-01 2018-12-31 C001183 28-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-19 2018-01-01 2018-12-31 C001183 10-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-17 2018-01-01 2018-12-31 C001183 1-6 2018-01-01 2018-12-31 C001183 0-10 2018-01-01 2018-12-31 C001183 7-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-7 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-09-30 C001183 7-20 2018-01-01 2018-12-31 C001183 10-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-4 2018-01-01 2018-12-31 C001183 0-49 2018-01-01 2018-12-31 C001183 0-52 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 6-11 2018-01-01 2018-12-31 C001183 21-7 2018-01-01 2018-12-31 C001183 25-12 2018-01-01 2018-12-31 C001183 0-3 2018-01-01 2018-12-31 C001183 16-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-15 2018-01-01 2018-12-31 C001183 14-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-6 2018-01-01 2018-12-31 C001183 3-10 2018-01-01 2018-12-31 C001183 24-14 2018-01-01 2018-12-31 C001183 2-3 2018-01-01 2018-12-31 C001183 9-2 2018-01-01 2018-12-31 C001183 27-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-17 2018-01-01 2018-12-31 C001183 0-1 2018-01-01 2018-03-31 C001183 21-10 2018-01-01 2018-12-31 C001183 12-9 2018-01-01 2018-12-31 C001183 10-15 2018-01-01 2018-12-31 C001183 7-12 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-24 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-12-31 C001183 0-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 19-14 2018-01-01 2018-12-31 C001183 SchedulePumpedStorageGeneratingPlantStatisticsAbstract 2018-01-01 2018-12-31 C001183 25-7 2018-01-01 2018-12-31 C001183 0-43 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-16 2018-01-01 2018-12-31 C001183 0-26 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-18 2018-01-01 2018-12-31 C001183 ferc:JulyMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-18 2018-01-01 2018-12-31 C001183 25-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-18 2018-01-01 2018-12-31 C001183 10-18 2018-01-01 2018-12-31 C001183 ScheduleOtherRegulatoryAssetsAbstract 2018-01-01 2018-12-31 C001183 0-28 2018-01-01 2018-12-31 C001183 13-16 2018-01-01 2018-12-31 C001183 20-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 0-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-16 2018-01-01 2018-12-31 C001183 3-7 2018-01-01 2018-12-31 C001183 9-8 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-12-31 C001183 0-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 10-13 2018-01-01 2018-12-31 C001183 0-27 2018-01-01 2018-12-31 C001183 3-18 2018-01-01 2018-12-31 C001183 4-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 26-11 2018-01-01 2018-12-31 C001183 13-17 2018-01-01 2018-12-31 C001183 0-5 2018-01-01 2018-12-31 C001183 16-4 2018-01-01 2018-12-31 C001183 16-19 2018-01-01 2018-12-31 C001183 11-11 2018-01-01 2018-12-31 C001183 0-4 2017-12-31 C001183 1-6 2018-01-01 2018-12-31 C001183 0-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-4 2018-01-01 2018-12-31 C001183 ScheduleInformationOnFormulaRatesAbstract 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-12-31 C001183 0-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-14 2018-01-01 2018-12-31 C001183 18-3 2018-01-01 2018-12-31 C001183 ferc:ElectricPlantInServiceMember ferc:ElectricUtilityMember 2018-01-01 2018-12-31 C001183 27-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 28-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-2 2018-01-01 2018-12-31 C001183 24-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-5 2018-01-01 2018-12-31 C001183 0-11 2018-01-01 2018-12-31 C001183 0-25 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-11 2018-01-01 2018-12-31 C001183 21-6 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-4 2018-12-31 C001183 ferc:ElectricUtilityMember 0-13 2018-01-01 2018-12-31 C001183 13-3 2018-01-01 2018-12-31 C001183 18-17 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-12-31 C001183 7-9 2018-01-01 2018-12-31 C001183 0-4 2018-01-01 2018-12-31 C001183 6-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 13-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-10 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 11-7 2018-01-01 2018-12-31 C001183 0-69 2018-01-01 2018-12-31 C001183 26-11 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 22-4 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 30-14 2018-01-01 2018-12-31 C001183 12-19 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-15 2018-01-01 2018-12-31 C001183 23-18 2018-01-01 2018-12-31 C001183 20-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-19 2018-01-01 2018-12-31 C001183 19-3 2018-01-01 2018-12-31 C001183 21-20 2018-01-01 2018-12-31 C001183 5-16 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 15-20 2018-01-01 2018-12-31 C001183 23-17 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-20 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 17-8 2018-01-01 2018-12-31 C001183 0-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-8 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 24-11 2018-01-01 2018-12-31 C001183 0-23 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 5-18 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-15 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 12-2 2018-01-01 2018-12-31 C001183 ferc:JanuaryMember EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0 2018-01-01 2018-12-31 C001183 0-8 2018-01-01 2018-12-31 C001183 19-17 2018-01-01 2018-12-31 C001183 30-7 2018-01-01 2018-12-31 C001183 0-77 2017-01-01 2017-12-31 C001183 ferc:TransmissionStudiesMember 9-16 2018-01-01 2018-12-31 C001183 31-3 2018-01-01 2018-12-31 C001183 25-16 2018-01-01 2018-12-31 C001183 16-17 2018-01-01 2018-12-31 C001183 18-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 20-11 2018-01-01 2018-12-31 C001183 26-12 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 21-2 2018-01-01 2018-12-31 C001183 ScheduleAllowanceInventoryAbstract 2018-01-01 2018-12-31 C001183 ScheduleTransmissionLineStatisticsAbstract 2018-01-01 2018-12-31 C001183 5-11 2018-01-01 2018-12-31 C001183 29-13 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-11 2018-01-01 2018-12-31 C001183 0-15 2018-01-01 2018-12-31 C001183 25-3 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 4-8 2018-01-01 2018-12-31 C001183 13-19 2018-01-01 2018-12-31 C001183 15-8 2018-01-01 2018-12-31 C001183 28-14 2018-01-01 2018-12-31 C001183 18-18 2018-01-01 2018-12-31 C001183 ferc:ElectricUtilityMember 0-7 2018-12-31 C001183 ferc:TransmissionStudiesMember 14-8 2018-01-01 2018-12-31 C001183 0-21 2018-01-01 2018-12-31 C001183 SchedulePurchasedPowerAbstract 2018-01-01 2018-12-31 C001183 16-7 2018-01-01 2018-12-31 C001183 0-6 2018-01-01 2018-12-31 C001183 22-9 2018-01-01 2018-12-31 C001183 22-20 2018-01-01 2018-12-31 C001183 23-11 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-6 2018-01-01 2018-12-31 C001183 0-33 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 23-15 2018-01-01 2018-12-31 C001183 ScheduleMonthlyTransmissionSystemPeakLoadAbstract 2018-01-01 2018-12-31 C001183 28-5 2018-01-01 2018-12-31 C001183 30-14 2018-01-01 2018-12-31 C001183 20-17 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 25-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 3-10 2018-01-01 2018-12-31 C001183 9-18 2018-01-01 2018-12-31 C001183 1-7 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 27-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 29-9 2018-01-01 2018-12-31 C001183 2-14 2018-01-01 2018-12-31 C001183 14-6 2018-01-01 2018-12-31 C001183 17-3 2018-01-01 2018-12-31 C001183 11-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 8-8 2018-01-01 2018-12-31 C001183 14-5 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 1-9 2018-01-01 2018-12-31 C001183 2-17 2018-01-01 2018-12-31 C001183 25-2 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-9 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 2-14 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 9-5 2018-01-01 2018-12-31 C001183 0-32 2018-01-01 2018-12-31 C001183 2-6 2018-01-01 2018-12-31 C001183 ferc:TransmissionStudiesMember 16-10 2018-01-01 2018-12-31 pure utr:MWh utr:MW 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)

California Independent System Operator Corporation
Year/Period of Report

End of:
2018
/
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 and Licensees 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 Forms 1 and 3-Q electronically through the forms submission software. Retain one copy of each report for your files. Any electronic submission must be created by using the forms submission software provided free by the Commission at its web site: http://www.ferc.gov/docs-filing/forms/form-1/elec-subm-soft.asp. The software is used to submit the electronic filing to the Commission via the Internet.
    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 for the year ended on which we have reported separately under date of , we have also reviewed 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. To further that effort, new selections, “Annual Report to Stockholders,” and “CPA Certification Statement” have been added to the dropdown “pick list” from which companies must choose when eFiling. Further instructions are found on the Commission’s website at http://www.ferc.gov/help/how-to.asp.
    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 http://www.ferc.gov/docs-filing/forms/form-1/form-1.pdf and http://www.ferc.gov/docs-filing/forms.asp#3Q-gas .
  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, submit the electronic filing using the form submission software only. 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.
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 be 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 salt 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

California Independent System Operator Corporation
02 Year/ Period of Report


End of:
2018
/
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)

250 Outcropping Way, Folsom, CA 95630
05 Name of Contact Person

Dennis Estrada
06 Title of Contact Person

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

250 Outcropping Way, Folsom, CA 95630
08 Telephone of Contact Person, Including Area Code

(916) 351-2235
09 This Report is An Original / A Resubmission

(1)
An Original

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

04/18/2019
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

Ryan Seghesio
02 Title

VP, CFO and Treasurer
03 Signature

04 Date Signed (Mo, Da, Yr)

04/18/2019
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
N/A
4
ScheduleOfficersAbstract
Officers
104
5
ScheduleDirectorsAbstract
Directors
105
6
ScheduleInformationOnFormulaRatesAbstract
Information on Formula Rates
106
N/A
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
11
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
N/A
16
ScheduleElectricPlantInServiceAbstract
Electric Plant in Service
204
17
ScheduleElectricPropertyLeasedToOthersAbstract
Electric Plant Leased to Others
213
N/A
18
ScheduleElectricPlantHeldForFutureUseAbstract
Electric Plant Held for Future Use
214
N/A
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
N/A
22
ScheduleMaterialsAndSuppliesAbstract
Materials and Supplies
227
N/A
23
ScheduleAllowanceInventoryAbstract
Allowances
228
N/A
24
ScheduleExtraordinaryPropertyLossesAbstract
Extraordinary Property Losses
230a
N/A
25
ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract
Unrecovered Plant and Regulatory Study Costs
230b
N/A
26
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract
Transmission Service and Generation Interconnection Study Costs
231
27
ScheduleOtherRegulatoryAssetsAbstract
Other Regulatory Assets
232
N/A
28
ScheduleMiscellaneousDeferredDebitsAbstract
Miscellaneous Deferred Debits
233
29
ScheduleAccumulatedDeferredIncomeTaxesAbstract
Accumulated Deferred Income Taxes
234
N/A
30
ScheduleCapitalStockAbstract
Capital Stock
250
N/A
31
ScheduleOtherPaidInCapitalAbstract
Other Paid-in Capital
253
N/A
32
ScheduleCapitalStockExpenseAbstract
Capital Stock Expense
254b
N/A
33
ScheduleLongTermDebtAbstract
Long-Term Debt
256
34
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract
Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax
261
N/A
35
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract
Taxes Accrued, Prepaid and Charged During the Year
262
36
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract
Accumulated Deferred Investment Tax Credits
266
N/A
37
ScheduleOtherDeferredCreditsAbstract
Other Deferred Credits
269
38
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract
Accumulated Deferred Income Taxes-Accelerated Amortization Property
272
N/A
39
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract
Accumulated Deferred Income Taxes-Other Property
274
N/A
40
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract
Accumulated Deferred Income Taxes-Other
276
N/A
41
ScheduleOtherRegulatoryLiabilitiesAbstract
Other Regulatory Liabilities
278
N/A
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
N/A
45
ScheduleSalesForResaleAbstract
Sales for Resale
310
N/A
46
ScheduleElectricOperationsAndMaintenanceExpensesAbstract
Electric Operation and Maintenance Expenses
320
47
SchedulePurchasedPowerAbstract
Purchased Power
326
N/A
48
ScheduleTransmissionOfElectricityForOthersAbstract
Transmission of Electricity for Others
328
N/A
49
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract
Transmission of Electricity by ISO/RTOs
331
50
ScheduleTransmissionOfElectricityByOthersAbstract
Transmission of Electricity by Others
332
N/A
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
N/A
55
ScheduleDistributionOfSalariesAndWagesAbstract
Distribution of Salaries and Wages
354
56
ScheduleCommonUtilityPlantAndExpensesAbstract
Common Utility Plant and Expenses
356
N/A
57
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract
Amounts included in ISO/RTO Settlement Statements
397
N/A
58
SchedulePurchasesSalesOfAncillaryServicesAbstract
Purchase and Sale of Ancillary Services
398
N/A
59
ScheduleMonthlyTransmissionSystemPeakLoadAbstract
Monthly Transmission System Peak Load
400
N/A
60
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract
Monthly ISO/RTO Transmission System Peak Load
400a
61
ScheduleElectricEnergyAccountAbstract
Electric Energy Account
401a
N/A
62
ScheduleMonthlyPeakAndOutputAbstract
Monthly Peaks and Output
401b
63
ScheduleSteamElectricGeneratingPlantStatisticsAbstract
Steam Electric Generating Plant Statistics
402
N/A
64
ScheduleHydroelectricGeneratingPlantStatisticsAbstract
Hydroelectric Generating Plant Statistics
406
N/A
65
SchedulePumpedStorageGeneratingPlantStatisticsAbstract
Pumped Storage Generating Plant Statistics
408
N/A
66
ScheduleGeneratingPlantStatisticsAbstract
Generating Plant Statistics Pages
410
N/A
0
ScheduleEnergyStorageOperationsLargePlantsAbstract
Energy Storage Operations (Large Plants)
414
67
ScheduleTransmissionLineStatisticsAbstract
Transmission Line Statistics Pages
422
N/A
68
ScheduleTransmissionLinesAddedAbstract
Transmission Lines Added During Year
424
N/A
69
ScheduleSubstationsAbstract
Substations
426
N/A
70
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract
Transactions with Associated (Affiliated) Companies
429
N/A
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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.

Ryan Seghesio Vice President/Chief Financial Officer/ Treasurer 250 Outcropping Way Folsom, CA 95630

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.

California- 1997

State of Incorporation:

Date of Incorporation:

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.

Not Applicable

(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.

Within the California ISO's Balancing Authority area, the ISO provides services pursuant to its FERC tariff. These services include open access transmission planning and a market for wholesale energy and related services.
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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.
N/A


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
President and Chief Executive Officer
Steve Berberich
661,500
2
Vice President of General Counsel and Chief Compliance
Roger Collanton
321,690
3
Vice President, Market and Infrastructure Development
Keith Casey
345,282
4
Vice President, Technology
Petar Ristanovic
329,961
5
Vice President, Operations
Eric Schmitt
317,931
6
Vice President, Market Quality and Renewable Integration
Mark Rothleder
329,720
7
Vice President, Regional and Federal Affairs, Regional s
Stacey Crowley
283,875
8
Vice President, Customer and State Affairs, Customer ans
Thomas Doughty
283,875
9
Vice President, Chief Financial Officer and Treasurer
Ryan Seghesio
275,000
10
Vice President, Human Resources
Jodi Ziemathis
250,000
11
Amounts reported in column "Salary for Year (c)"
12
represent base salary.


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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), abbreviated titles of the directors who are officers of the respondent.
  2. 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
CAISO Board of Governors
2
Angelina Galiteva
PO Box 639014, Folsom, CA, 95763-4400
3
David Olsen*
PO Box 639014, Folsom, CA, 95763-4400
4
Mark Ferron
PO Box 639014, Folsom, CA, 95763-4400
5
Ashutosh Bhagwat
PO Box 639014, Folsom, CA, 95763-4400
6
Richard Maullin
PO Box 639014, Folsom, CA, 95763-4400
7
* Chairman of the Board; The Company has no Executive
8
Committee
9
EIM Governing Body
10
Valerie Fong**
PO Box 639014, Folsom, CA, 95763-4400
11
Carl Linvill***
PO Box 639014, Folsom, CA, 95763-4400
12
John Prescott
PO Box 639014, Folsom, CA, 95763-4400
13
Kristine Schmidt
PO Box 639014, Folsom, CA, 95763-4400
14
Travis Kavulla
PO Box 639014, Folsom, CA, 95763-4400
15
**Chairman of the EIM Governing Body
16
***Vice Chair of the EIM Governing Body


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 (Checked by default - Not explicitly defined)
  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
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 Page 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest.
  11. (Reserved.)
  12. If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page.
  13. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period.
  14. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.

1. N/A

2. N/A

3. N/A

4. N/A

5. Boise-based Idaho Power and Powerex of Vancouver, British Columbia, successfully entered the western Energy Imbalance Market (EIM) in April 2018, allowing the ISO’s real-time power market to serve energy imbalances occurring within about 55 percent of the electric load in the Western Interconnection.

6. N/A

7. None

8. None

9. Please refer to the Note 12 Contingencies of the 2018 Form 1 Notes to the Financial Statements for materially important legal proceedings.

10. None

11. N/A

12. N/A

13. In February 2018, the ISO Board of Governors elected David Olsen to serve as Chair of the ISO Board of Governors, pursuant to Article III, section 4.3 of the ISO’s bylaws, effective February 16, 2018 to February 15, 2019, or as soon as practical thereafter until a successor is elected. Additionally, the ISO Board of Governors elected Angelina Galiteva to serve as Vice Chair of the ISO Board of Governors, whose role will include substituting for the Chair when the Chair is unable to fulfill his or her duties, for example, due to conflicts, absence, or unforeseen reasons, effective February 16, 2018 to February 15, 2019, or as soon as practical thereafter until a successor is elected.

 

Additionally, Governor Gavin Newsom appointed two new members to the ISO Board of Governors, Severin Borenstein and Mary Leslie, in January 2019, replacing a seat vacated by Mark Ferron and Richard Maullin whose terms expired on December 31, 2018.

 

In June 2018, Mr. Carl Linvill was re-appointed to a second term by the EIM Governing Body, which will expire in three years. The EIM Governing Body also named Mr. Travis Kavulla to a three-year term filling the seat vacated by Douglas Howe. The new term for Mr. Kavulla and Mr. Linvill are effective July 1, 2018. In addition, Valerie Fong was elected Chair, and Mr. Linvill was elected Vice Chair of the EIM Governing Body to terms of July 1, 2018 to June 30, 2019, respectively.

14. N/A


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
641,402,488
635,173,670
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200
16,854,065
16,293,194
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Enter Total of lines 2 and 3)
658,256,553
651,466,864
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)
200
491,176,799
472,569,151
6
UtilityPlantNet
Net Utility Plant (Enter Total of line 4 less 5)
167,079,754
178,897,713
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)
167,079,754
178,897,713
15
OtherElectricPlantAdjustments
Utility Plant Adjustments (116)
16
GasStoredUndergroundNoncurrent
Gas Stored Underground - Noncurrent (117)
17
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
18
NonutilityProperty
Nonutility Property (121)
19
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Prov. for Depr. and Amort. (122)
20
InvestmentInAssociatedCompanies
Investments in Associated Companies (123)
21
InvestmentInSubsidiaryCompanies
Investment in Subsidiary Companies (123.1)
224
23
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
228
24
OtherInvestments
Other Investments (124)
162,209,833
126,884,341
25
SinkingFunds
Sinking Funds (125)
26
DepreciationFund
Depreciation Fund (126)
27
AmortizationFundFederal
Amortization Fund - Federal (127)
28
OtherSpecialFunds
Other Special Funds (128)
356,470,413
342,414,487
29
SpecialFunds
Special Funds (Non Major Only) (129)
30
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
31
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
32
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Lines 18-21 and 23-31)
518,680,246
469,298,828
33
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
34
CashAndWorkingFunds
Cash and Working Funds (Non-major Only) (130)
35
Cash
Cash (131)
(a)
39,062,366
59,143,609
36
SpecialDeposits
Special Deposits (132-134)
137,326
137,220
37
WorkingFunds
Working Fund (135)
15,344
11,498
38
TemporaryCashInvestments
Temporary Cash Investments (136)
39
NotesReceivable
Notes Receivable (141)
40
CustomerAccountsReceivable
Customer Accounts Receivable (142)
6,260,739
1,793,498
41
OtherAccountsReceivable
Other Accounts Receivable (143)
298,692
899,091
42
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
43
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
44
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Assoc. Companies (146)
45
FuelStock
Fuel Stock (151)
227
46
FuelStockExpensesUndistributed
Fuel Stock Expenses Undistributed (152)
227
47
Residuals
Residuals (Elec) and Extracted Products (153)
227
48
PlantMaterialsAndOperatingSupplies
Plant Materials and Operating Supplies (154)
227
49
Merchandise
Merchandise (155)
227
50
OtherMaterialsAndSupplies
Other Materials and Supplies (156)
227
51
NuclearMaterialsHeldForSale
Nuclear Materials Held for Sale (157)
202/227
52
AllowanceInventoryAndWithheld
Allowances (158.1 and 158.2)
228
53
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
228
54
StoresExpenseUndistributed
Stores Expense Undistributed (163)
227
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)
6,624,466
6,713,211
58
AdvancesForGas
Advances for Gas (166-167)
59
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
1,078,833
889,092
60
RentsReceivable
Rents Receivable (172)
61
AccruedUtilityRevenues
Accrued Utility Revenues (173)
8,556,051
7,691,787
62
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
63
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
64
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
65
DerivativeInstrumentAssetsHedges
Derivative Instrument Assets - Hedges (176)
66
DerivativeInstrumentAssetsHedgesLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67
CurrentAndAccruedAssets
Total Current and Accrued Assets (Lines 34 through 66)
62,033,817
77,279,006
68
DeferredDebitsAbstract
DEFERRED DEBITS
69
UnamortizedDebtExpense
Unamortized Debt Expenses (181)
1,124,894
1,220,211
70
ExtraordinaryPropertyLosses
Extraordinary Property Losses (182.1)
230a
71
UnrecoveredPlantAndRegulatoryStudyCosts
Unrecovered Plant and Regulatory Study Costs (182.2)
230b
72
OtherRegulatoryAssets
Other Regulatory Assets (182.3)
232
73
PreliminarySurveyAndInvestigationCharges
Prelim. Survey and Investigation Charges (Electric) (183)
74
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges
Preliminary Natural Gas Survey and Investigation Charges 183.1)
75
OtherPreliminarySurveyAndInvestigationCharges
Other Preliminary Survey and Investigation Charges (183.2)
76
ClearingAccounts
Clearing Accounts (184)
2,067
17,955
77
TemporaryFacilities
Temporary Facilities (185)
78
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
7,523,336
6,393,856
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)
8,804,751
9,550,818
82
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234
83
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
84
DeferredDebits
Total Deferred Debits (lines 69 through 83)
17,455,048
17,146,930
85
AssetsAndOtherDebits
TOTAL ASSETS (lines 14-16, 32, 67, and 84)
765,248,865
742,622,477


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: Cash

 

2018

2017

1310011 Concentration Account

$ -

$ -

1310013 Disbursements Account

(890,060)

(101,793)

1310014 Payroll Account

(165,891)

(33,725)

1310025 Concentration-Wells Fargo

446,024

119,986

1310134 API Controlled Disbursement

-

-

1310023 LGIP Transmission Studies Deposit

966,584

(230)

Cash Equivalents - Investments

38,705,709

59,159,372

Total Cash/Cash Equivalents - Unrestricted

$ 39,062,366

$ 59,143,609

 

 

 

 

 

 

1280021 2009 Bonds Construction Fund

$ -

$ 8

1280183 Retiree Medical Plan Trust Acc

221

4,199

1240017 Investments- LGIP

4,888,399

6,003,463

1280173 Investments-Forefeited LGIP/SGIP

8,122,496

8,873,822

1280172 Trustee Cash (Market)

272,827,939

258,742,142

Total Cash/ Cash Equivalents - Restricted

$ 285,839,055

$ 273,623,634

 

 

 

Total Cash/Cash Equivalents Reported on Cash Flow

$ 324,901,420

$ 332,767,244

 


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
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
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
168,448,372
161,155,840
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118
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)
6,066,397
8,220,543
16
ProprietaryCapital
Total Proprietary Capital (lines 2 through 15)
162,381,975
152,935,297
17
LongTermDebtAbstract
LONG-TERM DEBT
18
Bonds
Bonds (221)
256
173,515,000
178,280,000
19
ReacquiredBonds
(Less) Reaquired Bonds (222)
256
20
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256
21
OtherLongTermDebt
Other Long-Term Debt (224)
256
22
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
7,243,251
7,857,004
23
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Debit (226)
24
LongTermDebt
Total Long-Term Debt (lines 18 through 23)
180,758,251
186,137,004
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases - Noncurrent (227)
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
28,134,548
28,115,161
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
34
AssetRetirementObligations
Asset Retirement Obligations (230)
35
OtherNoncurrentLiabilities
Total Other Noncurrent Liabilities (lines 26 through 34)
28,134,548
28,115,161
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
NotesPayable
Notes Payable (231)
38
AccountsPayable
Accounts Payable (232)
41,970,877
37,945,031
39
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
40
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
41
CustomerDeposits
Customer Deposits (235)
345,181,800
330,381,178
42
TaxesAccrued
Taxes Accrued (236)
262
1,304,531
1,271,106
43
InterestAccrued
Interest Accrued (237)
3,565,073
3,647,781
44
DividendsDeclared
Dividends Declared (238)
45
MaturedLongTermDebt
Matured Long-Term Debt (239)
46
MaturedInterest
Matured Interest (240)
47
TaxCollectionsPayable
Tax Collections Payable (241)
48
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
49
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
50
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
51
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
52
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
53
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54
CurrentAndAccruedLiabilities
Total Current and Accrued Liabilities (lines 37 through 53)
392,022,281
373,245,096
55
DeferredCreditsAbstract
DEFERRED CREDITS
56
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
57
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
266
58
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
59
OtherDeferredCredits
Other Deferred Credits (253)
269
1,951,810
2,189,919
60
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
61
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reaquired Debt (257)
62
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accum. Deferred Income Taxes-Accel. Amort.(281)
272
63
AccumulatedDeferredIncomeTaxesOtherProperty
Accum. Deferred Income Taxes-Other Property (282)
64
AccumulatedDeferredIncomeTaxesOther
Accum. Deferred Income Taxes-Other (283)
65
DeferredCredits
Total Deferred Credits (lines 56 through 64)
1,951,810
2,189,919
66
LiabilitiesAndOtherCredits
TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)
765,248,865
742,622,477


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 columnin 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 purches, and a summary of the adjustments made to balance sheet, income, and expense accounts.
  7. If any notes appearing in the report to stokholders 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
223,887,913
220,605,050
223,887,913
220,605,050
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
320
146,509,697
139,665,948
146,509,697
139,665,948
5
MaintenanceExpense
Maintenance Expenses (402)
320
28,641,554
27,595,880
28,641,554
27,595,880
6
DepreciationExpense
Depreciation Expense (403)
336
35,337,967
27,765,081
35,337,967
27,765,081
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336
9
AmortizationOfElectricPlantAcquisitionAdjustments
Amort. of Utility Plant Acq. Adj. (406)
336
10
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts
Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11
AmortizationOfConversionExpenses
Amort. of Conversion Expenses (407.2)
12
RegulatoryDebits
Regulatory Debits (407.3)
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262
183,543
54,468
183,543
54,468
15
IncomeTaxesOperatingIncome
Income Taxes - Federal (409.1)
262
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes - Other (409.1)
262
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision for Deferred Income Taxes (410.1)
234, 272
18
ProvisionForDeferredIncomeTaxesCreditOperatingIncome
(Less) Provision for Deferred Income Taxes-Cr. (411.1)
234, 272
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adj. - Net (411.4)
266
20
GainsFromDispositionOfPlant
(Less) Gains from Disp. of Utility Plant (411.6)
21
LossesFromDispositionOfServiceCompanyPlant
Losses from Disp. of Utility Plant (411.7)
113,898
113,898
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
24
AccretionExpense
Accretion Expense (411.10)
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)
210,672,761
194,967,479
210,672,761
194,967,479
27
NetUtilityOperatingIncome
Net Util Oper Inc (Enter Tot line 2 less 25)
13,215,152
25,637,571
13,215,152
25,637,571
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)
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
37
InterestAndDividendIncome
Interest and Dividend Income (419)
2,324,626
3,106,621
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
161,118
53,253
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
29,897
55,440
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
41
OtherIncome
TOTAL Other Income (Enter Total of lines 31 thru 40)
2,515,641
3,215,314
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
979
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
45
Donations
Donations (426.1)
46
LifeInsurance
Life Insurance (426.2)
47
Penalties
Penalties (426.3)
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Exp. for Certain Civic, Political & Related Activities (426.4)
49
OtherDeductions
Other Deductions (426.5)
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
979
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Inc. Taxes (410.2)
234, 272
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Cr. (411.2)
234, 272
57
InvestmentTaxCreditAdjustmentsNonutilityOperations
Investment Tax Credit Adj.-Net (411.5)
58
InvestmentTaxCredits
(Less) Investment Tax Credits (420)
59
TaxesOnOtherIncomeAndDeductions
TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
2,515,641
3,214,335
61
InterestChargesAbstract
Interest Charges
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
8,572,717
8,766,425
63
AmortizationOfDebtDiscountAndExpense
Amort. of Debt Disc. and Expense (428)
95,317
97,922
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reaquired Debt (428.1)
746,066
766,458
65
AmortizationOfPremiumOnDebtCredit
(Less) Amort. of Premium on Debt-Credit (429)
613,753
630,528
66
AmortizationOfGainOnReacquiredDebtCredit
(Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67
InterestOnDebtToAssociatedCompanies
Interest on Debt to Assoc. Companies (430)
68
OtherInterestExpense
Other Interest Expense (431)
362,086
94,777
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)
401,163
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
8,438,261
8,504,337
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
7,292,532
20,347,569
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)
(a)(b)(c)
7,292,532
20,347,569


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 261 - Schedule - Reconciliation of Reported Net Income with Taxable Income for Federal Income Taxes, Row: 1, Column: b, Value: 0
(b) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 122a - Schedule - Statement of Accumulated Other Comprehensive Income, Comprehensive Income, and Hedging Activities, Row: 9, Column: i, Value: 7292531
(c) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 120 - Schedule - Statement of Cash Flows, Row: 2, Column: b, Value: 7292531

Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report


End of:
2018
/
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 122-123.
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
161,155,840
140,651,080
2
ChangesAbstract
Changes
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
4
AdjustmentsToRetainedEarningsCreditAbstract
Adjustments to Retained Earnings Credit
4.1
AdjustmentsToRetainedEarningsCredit
Prior period revision to OPEB related cost
157,191
4.2
AdjustmentsToRetainedEarningsCredit
4.3
AdjustmentsToRetainedEarningsCredit
4.4
AdjustmentsToRetainedEarningsCredit
4.5
AdjustmentsToRetainedEarningsCredit
4.6
AdjustmentsToRetainedEarningsCredit
4.7
AdjustmentsToRetainedEarningsCredit
4.8
AdjustmentsToRetainedEarningsCredit
4.9
AdjustmentsToRetainedEarningsCredit
4.10
AdjustmentsToRetainedEarningsCredit
9
AdjustmentsToRetainedEarningsCredit
TOTAL Credits to Retained Earnings (Acct. 439)
157,191
10
AdjustmentsToRetainedEarningsDebitAbstract
Adjustments to Retained Earnings Debit
10.1
AdjustmentsToRetainedEarningsDebit
10.2
AdjustmentsToRetainedEarningsDebit
10.3
AdjustmentsToRetainedEarningsDebit
10.4
AdjustmentsToRetainedEarningsDebit
10.5
AdjustmentsToRetainedEarningsDebit
10.6
AdjustmentsToRetainedEarningsDebit
10.7
AdjustmentsToRetainedEarningsDebit
10.8
AdjustmentsToRetainedEarningsDebit
10.9
AdjustmentsToRetainedEarningsDebit
10.10
AdjustmentsToRetainedEarningsDebit
15
AdjustmentsToRetainedEarningsDebit
TOTAL Debits to Retained Earnings (Acct. 439)
16
BalanceTransferredFromIncome
Balance Transferred from Income (Account 433 less Account 418.1)
7,292,532
20,347,569
17
AppropriationsOfRetainedEarningsAbstract
Appropriations of Retained Earnings (Acct. 436)
17.1
AppropriationsOfRetainedEarnings
17.2
AppropriationsOfRetainedEarnings
17.3
AppropriationsOfRetainedEarnings
17.4
AppropriationsOfRetainedEarnings
22
AppropriationsOfRetainedEarnings
TOTAL Appropriations of Retained Earnings (Acct. 436)
23
DividendsDeclaredPreferredStockAbstract
Dividends Declared-Preferred Stock (Account 437)
23.1
DividendsDeclaredPreferredStock
23.2
DividendsDeclaredPreferredStock
23.3
DividendsDeclaredPreferredStock
23.4
DividendsDeclaredPreferredStock
23.5
DividendsDeclaredPreferredStock
29
DividendsDeclaredPreferredStock
TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30
DividendsDeclaredCommonStockAbstract
Dividends Declared-Common Stock (Account 438)
30.1
DividendsDeclaredCommonStock
30.2
DividendsDeclaredCommonStock
30.3
DividendsDeclaredCommonStock
30.4
DividendsDeclaredCommonStock
30.5
DividendsDeclaredCommonStock
36
DividendsDeclaredCommonStock
TOTAL Dividends Declared-Common Stock (Acct. 438)
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)
168,448,372
161,155,840
AppropriatedRetainedEarningsAbstract
APPROPRIATED RETAINED EARNINGS (Account 215)
.1
AppropriatedRetainedEarnings
.2
AppropriatedRetainedEarnings
.3
AppropriatedRetainedEarnings
.4
AppropriatedRetainedEarnings
.5
AppropriatedRetainedEarnings
.6
AppropriatedRetainedEarnings
.7
AppropriatedRetainedEarnings
.8
AppropriatedRetainedEarnings
.9
AppropriatedRetainedEarnings
.10
AppropriatedRetainedEarnings
.11
AppropriatedRetainedEarnings
.12
AppropriatedRetainedEarnings
.13
AppropriatedRetainedEarnings
.14
AppropriatedRetainedEarnings
45
AppropriatedRetainedEarnings
TOTAL Appropriated Retained Earnings (Account 215)
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract
APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46
AppropriatedRetainedEarningsAmortizationReserveFederal
TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47
AppropriatedRetainedEarningsIncludingReserveAmortization
TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48
RetainedEarnings
TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)
168,448,372
161,155,840
UnappropriatedUndistributedSubsidiaryEarningsAbstract
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49
UnappropriatedUndistributedSubsidiaryEarnings
Balance-Beginning of Year (Debit or Credit)
50
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings for Year (Credit) (Account 418.1)
51
DividendsReceived
(Less) Dividends Received (Debit)
52
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
52.1
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
53
UnappropriatedUndistributedSubsidiaryEarnings
Balance-End of Year (Total lines 49 thru 52)


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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)
(a)(b)(c)
7,292,532
20,347,569
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
35,337,967
27,765,081
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of Debt Expenses
841,384
864,380
5.2
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of Bond Premium
613,753
630,528
5.3
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Capitalized Interest Expense
161,118
53,253
8
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
9
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustment (Net)
10
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
(d)
5,985,449
(l)
1,203,851
11
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
12
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
13
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
4,161,097
2,090,103
14
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
15
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
16
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
17
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
18
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other (provide details in footnote):
18.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Lease Termination Costs/Loss on Disposal of Asset/Abandoned Software
112,919
18.2
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Net Increase in Other Deferred Credits
(e)
238,109
72,287
22
NetCashFlowFromOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)
40,956,786
49,100,801
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)
27
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
28
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
(f)
21,692,125
(m)
20,308,814
29
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
30
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
31
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other (provide details in footnote):
34
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 26 thru 33)
(g)
21,692,125
(n)
20,308,814
36
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
37
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
39
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Investments in and Advances to Assoc. and Subsidiary Companies
40
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies
Contributions and Advances from Assoc. and Subsidiary Companies
41
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract
Disposition of Investments in (and Advances to)
42
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44
PurchaseOfInvestmentSecurities
Purchase of Investment Securities (a)
(h)
73,633,311
(o)
37,418,823
45
ProceedsFromSalesOfInvestmentSecurities
Proceeds from Sales of Investment Securities (a)
38,307,818
42,324,485
46
LoansMadeOrPurchased
Loans Made or Purchased
47
CollectionsOnLoans
Collections on Loans
49
NetIncreaseDecreaseInReceivablesInvestingActivities
Net (Increase) Decrease in Receivables
50
NetIncreaseDecreaseInInventoryInvestingActivities
Net (Increase) Decrease in Inventory
51
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities
Net (Increase) Decrease in Allowances Held for Speculation
52
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
53
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other (provide details in footnote):
57
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)
57,017,618
15,403,152
59
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
60
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
61
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Long-Term Debt (b)
62
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Preferred Stock
63
ProceedsFromIssuanceOfCommonStockFinancingActivities
Common Stock
64
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other (provide details in footnote):
66
NetIncreaseInShortTermDebt
Net Increase in Short-Term Debt (c)
67
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
67.1
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Receipts from Market Participants (See Note 3)
560,856,688
506,012,357
67.2
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Payments to Market Participants (See Note 3)
546,056,066
571,488,070
70
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total 61 thru 69)
14,800,622
65,475,713
72
PaymentsForRetirementAbstract
Payments for Retirement of:
73
PaymentsForRetirementOfLongTermDebtFinancingActivities
Long-term Debt (b)
(i)
4,765,000
(p)
4,625,000
74
PaymentsForRetirementOfPreferredStockFinancingActivities
Preferred Stock
75
PaymentsForRetirementOfCommonStockFinancingActivities
Common Stock
76
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Increase in Special Deposits
(j)
107
(q)
52
76.2
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Net (Increase) in Other Special Funds
(k)
1,840,507
(r)
8,938,188
78
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
80
DividendsOnPreferredStock
Dividends on Preferred Stock
81
DividendsOnCommonStock
Dividends on Common Stock
83
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)
8,195,008
61,162,577
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)
7,865,824
27,464,928
88
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
332,767,244
360,232,172
90
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
324,901,420
332,767,244


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 261 - Schedule - Reconciliation of Reported Net Income with Taxable Income for Federal Income Taxes, Row: 1, Column: b, Value: 0
(b) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 122a - Schedule - Statement of Accumulated Other Comprehensive Income, Comprehensive Income, and Hedging Activities, Row: 9, Column: i, Value: 7292531
(c) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 120 - Schedule - Statement of Cash Flows, Row: 2, Column: b, Value: 7292531
(d) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
Original value: -5985449
(e) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities

 

2018

2017

 

 

 

Fines Subject to Refund

$ 1,805,230

$ 2,167,429

Advances for Leasehold Improvements

-

-

Unearned Revenue

-

-

EIM Fees

-

22,491

Accrued Taxes

146,580

 

 

$ 1,951,810

$ 2,189,919

 

 

 

 

 

 

 

 

 

Cash Flow Statement Presentation of Net Change:

 

 

 

 

 

Net Change

$ (238,109)

$ (72,287)

 

 

 

Payment of Generator Noncompliance Fines Refund Obligation

 

 

Net Increase in Other Deferred Credits

$ (238,109)

$ (72,287)

 

(f) Concept: GrossAdditionsToCommonUtilityPlantInvestingActivities
Original value: -21692125
(g) Concept: CashOutflowsForPlant
Original value: -21692125
(h) Concept: PurchaseOfInvestmentSecurities
Original value: -73633311
(i) Concept: PaymentsForRetirementOfLongTermDebtFinancingActivities
Original value: -4765000
(j) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Original value: -107
(k) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Original value: -1840507
(l) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
Original value: -1203851
(m) Concept: GrossAdditionsToCommonUtilityPlantInvestingActivities
Original value: -20308814
(n) Concept: CashOutflowsForPlant
Original value: -20308814
(o) Concept: PurchaseOfInvestmentSecurities
Original value: -37418823
(p) Concept: PaymentsForRetirementOfLongTermDebtFinancingActivities
Original value: -4625000
(q) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Original value: -52
(r) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Original value: 8938188

Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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.

1. Organization and Operations

 

The Company, a nonprofit public benefit corporation, is responsible for ensuring the reliable and efficient use of the transmission grid in most of California and a part of Nevada. The Company operates this grid, which is one of the largest and most modern power grids in the world, as a balancing authority within the Western Electricity Coordinating Council. The Company conducts comprehensive planning for the future development of this grid.

 

The Company’s wholesale energy market is the vehicle for providing open-access transmission service to users of the transmission grid. It includes a day-ahead market for all twenty-four hours of the next operating day, and a real-time market that schedules resources in 15 minute intervals and dispatches them in 5 minute intervals. The day-ahead market clears supply and demand offers for short-term energy purchases and sales. The real-time market clears supply offers and the Company’s forecast of demand. Together, these enable the economic scheduling and dispatch of generating resources to maintain continuous balance of supply and demand and management of congestion on the grid. The market also procures reserve capacity or ancillary services to maintain reliable operation under unexpected changes in grid conditions.

 

The Company continues to develop market enhancements to increase reliability, efficiency and the accuracy of market results. The current market prices energy at the points it enters and leaves the grid, which increases transparency by sending signals for competitive investments in transmission and generation. The market operates on an advanced and flexible platform helping to integrate renewable resources as well as demand response. These enhancements increase the functionality and flexibility of the market system to meet the on-going needs of market participants.

 

The Company operates the Western Energy Imbalance Market (the “EIM”). This extension of the Company’s real-time energy market facilitates transactions with and among several balancing authority areas in the western interconnection that are not a part of the grid the Company operates. The EIM provides reliability, efficiency and renewable integration benefits to the West while also providing economic benefits to participants. The broader footprint for the real-time market provides more opportunities to integrate cleaner sources of energy, such as wind and solar, that may be produced in one area but needed in another. Seven balancing authorities are participating as of the end of 2018 and several others have committed to participate in the future.

 

In addition, the Company also performs a settlement and clearing function by charging and collecting payments from users of these services and paying providers of such services. Cash held by the Company on behalf of market participants is recorded in a restricted asset account with a corresponding liability due to market participants in the Balance Sheet. Except for the retention of restricted assets noted above, the Company’s financial statements reflect a net reporting of market activities wherein the financial statements do not include the revenues and expenses, cash flows, or assets and liabilities associated with the market transactions it facilitates. Grid Management Charge (“GMC”) revenues have a priority claim against any market-related receipts. Any market defaults are allocated to market participants.

 

The Company is regulated by the Federal Energy Regulatory Commission (“FERC”) and complies with standards set by the North American Electric Reliability Corporation and the Western Electricity Coordinating Council. A five-member Board of Governors (the “Board”) appointed by the Governor of California and confirmed by the California State Senate governs the Company.

 

 

 

 

 

 

 

 

 

 

2. Summary of Significant Accounting Policies

 

Method of accounting

The accompanying financial statements have been prepared in conformity with the requirements of the FERC, as set forth in its applicable Uniform System of Accounts and published accounting releases. Accordingly, as required by the FERC, certain information has been presented differently or has been excluded from that which would be required by accounting principles generally accepted in the United States of America (“GAAP”). Such differences include expense recognition related to the post-employment medical benefit plan, accounting for certain investments, the classification of long-term debt, balance sheet captions used for certain assets and liabilities, and the presentation of cash flows, as specified by the FERC. Additionally, certain disclosures required by GAAP are not required to be presented by the FERC.

 

Net presentation of market activity

The Company is a central counterparty to the market transactions that it financially settles, with certain limited exceptions. The Company is a buyer to every seller and a seller to every buyer, but market participants are responsible for supplying electricity and other services to their customers. The Company’s market participants are the primary obligors with respect to those obligations. In the event of a market default, the defaulted amount is allocated among market participants, in accordance with the tariff. Market participants continue to bear the credit risk associated with any financial defaults by other market participants. Accordingly, the Company’s financial statements continue to reflect a net reporting of market activities and exclude the revenues and expenses, cash flows, and assets and liabilities associated with the market transactions the Company facilitates.

 

Use of estimates

The preparation of the financial statements in conformity with GAAP requires management to make estimates and assumptions that affect reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could materially differ from these, and other, estimates.

 

Utility plant

Fixed assets are recorded at cost. Depreciation is computed using the straight-line method over the estimated useful lives of assets. Most of the Company’s investment in fixed assets consists of the headquarters building and the backup facility, both of which are being depreciated over twenty to thirty years, and information systems, which are being depreciated over three to seven years. The cost of improvements to or replacement of fixed assets is capitalized. Interest incurred during development is capitalized. When assets are retired or otherwise disposed of, the cost and related depreciation are removed from the accounts and any resulting gain or loss is reflected in the Company’s Statement of Income for the period. Repair and maintenance costs are expensed when incurred. The Company capitalizes direct costs of salaries and certain indirect costs to develop or obtain software for internal use. Costs related to software development during the preliminary stage of a project and training and maintenance costs are expensed as incurred. Costs related to abandoned projects are expensed when the decision to abandon is made.

 

Cash and cash equivalents

Cash and cash equivalents are included in various funds the use of which is either unrestricted or restricted. Cash and cash equivalents are comprised of cash in bank accounts, money market funds, and other highly liquid investments with original maturities of three months or less. Cash and cash equivalents are unrestricted unless specifically restricted by bond indentures or the tariff.

 

Other property and investments

Other property and investments include other investments and other special funds. Other investments have maturities of more than three months and include government and federal agency securities, corporate bonds, certificates of deposits (“CDs”) and equity and fixed income mutual funds. Investments are carried at fair value. Income on investments and the gain or loss on the fair value of instruments are recorded as a component of interest income.

 

Other special funds include cash and cash equivalents restricted by the tariff for market participants, bond indenture agreements for capital expenditures, funds held in trust for employee retirement plans and amounts on deposit for generator interconnection studies.

 

Current and accrued assets

Current and accrued assets include cash in bank accounts, special deposits, customer accounts receivable, other accounts receivable, prepayments, interest and dividends receivable, and accrued utility revenues.

 

Special deposits include cash, cash equivalents and investments restricted for debt service that are held by a bond trustee under an indenture agreement for scheduled repayments of bond principal and for a debt service reserve fund. Investments, which include government and federal agency securities and corporate bonds, are carried at fair value.

 

Accrued utility revenues and revenue recognition

The GMC is based on rates filed with the FERC and is designed to recover the Company’s operating costs, capital expenditures, debt service costs, and to provide for an operating reserve. The GMC billings are recognized as revenue. The initial billings are based on estimated meter data submitted by market participants and therefore may be subject to adjustment over time to reflect the difference between actual meter data and initial estimates.

 

The GMC is comprised of the following three service categories: market services, system operations and congestion revenue rights services.

 

The operating reserve is calculated separately for each GMC service category and accumulates until the reserve becomes fully funded (at 15% of budgeted annual operating costs for each rate service category). At December 31, 2018, the operating reserve for each service category was fully funded. In accordance with the tariff, any surplus operating reserve balance is applied as a reduction in revenue requirements in the following year. The tariff allows GMC rates to be adjusted not more than once per quarter. The rate for a service category is adjusted if the difference in actual versus projected volumes used to set the rate is equal or greater than 2%, or if the difference in actual versus estimated annual revenues for the service category is equal or greater than $1.0 million. On August 1, 2018, rates for system operations and market services categories were adjusted but no adjustments were made in 2017.

In addition, the Company bills the participants of the EIM an administrative charge based on gross imbalance EIM volumes and at a rate that is developed annually to recover the ongoing costs of operating the EIM. The EIM administrative charge is included in other revenues of the Company.

Generator interconnection studies

The Company is responsible for conducting generator interconnection studies at the request of project sponsors who are developing generating plants that would become connected to the transmission grid operated by the Company. The project sponsors are required to make a deposit before any studies are performed. Sponsors may withdraw from the studies at any time.

In accordance with the tariff, the Company charges the project sponsors the actual costs of the studies. Related study costs include both internal costs and external costs and are recorded, when incurred, as operating expenses. As costs are incurred, the Company recognizes revenue for the same amount, which is recorded as a component of operating revenues. The Company applies the deposits against the related receivable as costs are incurred. Certain deposits related to projects abandoned by the project sponsors are retained by the Company and distributed in accordance with the tariff. These distributions do not result in revenues or expenses recognized by the Company.

 

Deferred debits

Deferred debits consist primarily of debt issuance costs, which are amortized over the life of the bonds using the bonds outstanding method, which approximates the effective interest method.

Compensated absences

The Company accrues vacation leave when the employee becomes eligible for the benefit. The Company does not record sick leave or other leave as a liability since there are no cash payments for sick leave or other leave made when employees terminate or retire. At December 31, 2018 and 2017, the total accrued liability for vacation was $9.4 million and $9.0 million, respectively.

 

Other deferred credits

Other deferred credits consist primarily of liabilities related to generator noncompliance fines. From December 8, 2000 through June 30, 2001, the Company assessed noncompliance fines on participating generators that failed to fully comply with dispatch instructions when the Company was seeking to prevent an imminent or threatened system emergency. In accordance with the tariff, these fines are retained by the Company. The Company recorded the net realizable amount of such fines as revenue when the underlying noncompliance event occurred. However, the amount of the fines, which were based on the price of energy at the time has changed over time in response to developments in the still ongoing litigation over the California electricity crisis that have changed those prices. The Company adjusts such amounts in recognition of these developments, which affect the ultimate recognition of the fines charged and payments of the liability.

 

Income taxes

The Company is exempt from federal income tax under Section 501(c)(3) of the U.S. Internal Revenue Service (“IRS”) Code and is exempt from California State franchise income taxes.

 

Concentration of credit risk

Financial instruments that subject the Company to credit risk consist primarily of accounts receivable relating to GMC billings due from market participants, cash and cash equivalents and investments.

 

Most of the Company's receivables are due from entities in the energy industry, including utilities, generation owners and other electricity market participants. For the years ended December 31, 2018 and 2017, approximately 43 percent and 47 percent of GMC revenues, respectively, were from two market participants.

 

GMC revenues have a priority claim against any market-related receipts, which means that even if an entity defaults on an invoice containing a GMC charge, the Company receives the full GMC so long as sufficient funds were received on other market invoices.

 

The Company's concentration of credit risk related to its investment portfolio is the risk attributed to the magnitude of investments in a single issuer. The Company’s investment policy limits investments in any single issuer to no more than 5% of the portfolio, with exceptions relating to obligations issued by or fully guaranteed as to principal and interest by the United States, federal agencies or United States government sponsored enterprises, pooled investments such as money market funds, and investments procured in connection with Company bond offerings. As of December 31, 2018, other than the security exceptions described in the investment policy, the Company had no investments in any one issuer representing more than 5% of total cash and cash equivalents and investments.

 

In October 2016, the Securities and Exchange Commission (“SEC”) introduced new Money Market Fund rules. The new rules require the use of a floating net asset (“NAV”) for institutional prime money market funds and provide boards with the ability to impose liquidity fees, as well as implement redemption gates, for all non-governmental money market funds during periods of stress in the financial markets. Under normal circumstances a floating NAV money market fund investment would continue to meet the definition of a cash equivalent. However, in the event credit or liquidity issues arise causing a meaningful decrease of the money market investments below $1.0000 per share the classification of such investments as cash equivalents may not be appropriate. There were no credit or liquidity issues that resulted in meaningful decreases in the Company’s money market investments in 2018 and 2017. Therefore, amounts invested in money market funds remain classified as cash equivalents.

 

New Accounting Guidance

In February 2016, FASB issued guidance in ASU 2016-02 Leases (Topic 842) which will require organizations that lease assets, referred to as lessees, with terms of more than twelve months to recognize on the balance sheet the assets and liabilities for the rights and obligations created by leases. The guidance will also require disclosures to help investors and other financial statement users better understand the amount, timing, and uncertainty of cash flows arising from leases. For public companies, the ASU is effective for fiscal years, and interim within those fiscal years, beginning after December 15, 2018. For all other organizations, the ASU is effective after fiscal years beginning after December 15, 2019 and interim periods within fiscal years beginning after December 15, 2020. The Company is currently evaluating this guidance to determine any impact to the financial statements.

 

In 2016, FASB introduced ASU 2016-18 (Topic 230) Restricted Cash. The amendments in this update require that a Statement of Cash Flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the Statement of Cash Flows. The amendments in this update do not provide a definition of restricted cash or restricted cash equivalents. The Company has adopted FASB ASU 2016-18 (Topic 230) for the period ending December 31, 2018 and the presentation of the restricted cash or restricted cash equivalents are reflected in the Statement of Cash Flows. 

 


3. Customer Deposits

 

Customer deposits, which are cash and cash equivalents restricted for market participants, consists of amounts held by the Company to be remitted to market participants or others on their behalf. The balance of customer deposits at December 31 is as follows (in thousands):

 

[image]

 

Security deposits are amounts received from market participants who are required to post collateral for their transactions in the Company’s markets. Market funds pending settlement consist of amounts collected during the settlement and clearing function that will pass through to market participants in subsequent periods. Pass-through fees due to others consist of amounts collected from market participants that will be paid to market participants for summer reliability, startup costs and emission costs. Generator interconnection study deposits are amounts collected for future studies. Non-refundable deposits consist of interconnection amounts which are non-refundable to project sponsors in accordance with tariff requirements.

 

These amounts are reflected in the Balance Sheet as Customer Deposits, a liability account, and as a component of Other Special Funds, an asset account.

 


4. Other Investments, Other Special Funds and Special Deposits

 

Other investments, other special funds and special deposits consist of the following at December 31 (in thousands):

 

[image]

 

 

 

In addition, the Company recognized a loss on investments of $1.4 million at December 31, 2018 and a gain on investments of $0.3 million at December 31, 2017. The gains and losses are included in Interest Income. For the years ended December 31, 2018 and 2017, the disaggregated gains and losses are as follows (in thousands):

 

[image]

 

 

 


5. Utility Plant

 

Utility plant consists of the following at December 31 (in thousands):

 

[image]

 

 

The Company capitalized interest related to the development of fixed assets of $0.2 million and $0.5 million for the years ending December 31, 2018 and 2017, respectively.


6. Generator Noncompliance Fines

 

In 2000 and 2001, the Company billed generator noncompliance fines to market participants, of which the Company collected $60.7 million. Generally, these fines were assessed at a rate corresponding to twice the highest price paid in the Company’s markets for energy. Because the prices for this period are being adjusted as a result of the Federal Energy Regulatory Commission Refund Case, as described in Note 12, the amount of the fines to be retained by the Company is being reduced, with any surplus collections being refunded with interest to market participants. The Company accrues interest in accordance with the rulings of the Federal Energy Regulatory Commission rulings on the portion of fines collected in excess of the estimated realizable amount, which is to be refunded to market participants when the amounts are settled. The ultimate settlement of fines is expected after the conclusion of the proceedings in the Federal Energy Regulatory Commission Refund Case and the financial settlement of the California Power Exchange (“Cal PX”).

Based on estimates of the mitigated energy prices, the Company recorded fine revenues totaling $29.5 million, resulting in a refund liability of $31.2 million before interest. The Company reduced its refund liability (and associated interest obligation) by distributing funds to market participants that approximately equal its refund liability in connection with settlement agreements approved by the Federal Energy Regulatory Commission, including a distribution of $43.9 million on December 31, 2010.

Each year, the Company adjusts its estimated refund liability based on updated information it obtains related to interest and other factors that will serve to change the estimated amount of generator fine proceeds the Company will ultimately retain, which consequently modifies the generator fine collections that will be returned to market participants.

Based on estimates obtained in 2018 from parties involved in these proceedings and an updated estimate of the proportionate allocation of shortfalls to the Company in 2018, there was a decrease in the estimated liability of $0.4 million. As of December 31, 2018, the Company estimates the remaining liability (including interest) related to generator noncompliance fines to be $1.8 million.

There are significant uncertainties associated with the final settlement of generator noncompliance fines. While management’s estimated liability at December 31, 2018 is based on the best information available, adjustments are likely to occur in the future to the estimated liability associated with interest and other shortfalls that will be incurred by the Cal PX, and allocated to the Company in connection with final disposition of the funds and obligations arising from the events of 2000 and 2001.

 


7. Bonds

 

Bonds consist of the following at December 31 (in thousands):

 

[image]

 

 

Scheduled future debt service payments as of December 31, 2018, are as follows (in thousands):

 

[image]

 

The Series 2013 bonds are supported by a pledge of the Company’s revenues and operating reserves. In addition, the bonds are supported by a deed of trust on the Company’s headquarters building and land.

 

Interest expense recorded by the Company related to long-term debt includes interest paid on the bonds (net of interest capitalized to fixed assets), and amortization of the bond issuance costs, loss on refunding and the bond premiums.


8. Derivative Financial Instrument – Congestion Revenue Rights (“CRRs”)

As described in Note 2, the Company is the central counterparty to market participant transactions which includes CRRs. CRRs are financial instruments that enable market participants to reduce their congestion-related price risk when delivering or selling energy on the grid. A CRR provides an economic hedging mechanism against congestion charges that can be transacted by market participants separately from transmission services. These instruments are considered derivative financial instruments for accounting purposes, which would require presentation at fair value if they were recognized as assets and liabilities of the Company.

Consistent with its role in facilitating other market transactions, the Company facilitates the allocation, auctioning and ultimate settlement of CRRs in its market, but does not have economic risks and rewards associated with these financial instruments. Any market defaults are allocated to market participants. As such they are not recognized as assets and liabilities in the Company’s Balance Sheet. However, unlike other market transactions administered by the Company, CRRs can be outstanding for extended periods of time. At December 31, 2018, the average life of the Company’s CRRs was 3.9 years and there were a total of 100 CRR holders, compared to 4.0 years and 102 CRR holders at December 31, 2017. The estimated net fair value of both the CRR assets and liabilities as of December 31, 2018 was $940.5 million related to a total of 610,212 megawatts, which vary in length from one month to several years. This is compared to $555.5 million related to a total of 929,488 megawatts at December 31, 2017. The value of each megawatt of CRR is a function of numerous factors including the length of period the CRR covers.

While these amounts are not presented in the Balance Sheet, their estimated net fair value is disclosed for informational purposes given their longer term nature. Their fair value was determined based on several factors including actual auction prices transacted in the most recent annual and monthly auction processes, the Company’s models which calculate the estimated value of all transmission constraints, net present value discounting and other factors. In addition to the high level of uncertainty associated with these inputs to the valuation calculation model, changes to actual or anticipated flows and constraints on the transmission system managed by the Company or in the value of electricity flowing on the transmission system create volatility that can significantly affect CRR values. Changes in generation, load, weather, and transmission outages are other factors that can have immediate and significant impact on CRR values.

 

The following is a summary of CRR megawatts, by type, outstanding at December 31, 2018:

 

[image]

 

 

The following is a summary of CRR megawatts, by type, outstanding at December 31, 2017:

 

[image]

 

9. Fair Value of Financial Instruments

Accounting guidance for fair value measurement requires entities to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The standard establishes a three-tier fair value hierarchy based on the level of independent, objective evidence surrounding the inputs used to measure fair value. A financial instrument’s categorization within the fair value hierarchy is based upon the lowest level of input that is significant to the fair value measurement. The fair value hierarchy is as follows:

Level 1: Applies to assets or liabilities for which there are quoted prices in active markets that are accessible at the measurement date for identical unrestricted assets or liabilities.

Level 2: Applies to assets or liabilities for which there are inputs other than quoted prices that are observable for the asset or liability such as quoted prices for similar assets or liabilities in active markets; quoted prices for identical assets or liabilities in markets with insufficient volume or infrequent transactions (less active markets); or model-derived valuations in which significant inputs and significant value drivers are observable or can be derived principally from, or corroborated by, observable market data.

Level 3: Applies to assets or liabilities for which there are unobservable inputs to the valuation methodology that are significant to the measurement of the fair value of the assets or liabilities.

The Company’s assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability. Financial assets and liabilities are classified in their entirety based on the level of input that is considered most significant to the fair value measurement.

 

The Company’s assets measured at fair value on a recurring basis at December 31, 2018, were as follows (in thousands):

[image]

The Company’s assets measured at fair value on a recurring basis at December 31, 2017, were as follows (in thousands):

[image]

Level 1 money market funds, publicly traded mutual funds, and employee retirement plan trust accounts are determined by using quoted prices in active markets. Level 2 fixed income securities are priced using quoted market prices for similar instruments or nonbinding market prices that are corroborated by observable market data. Level 3 assets are non-negotiable instruments which require the use of unobservable inputs in determining fair value.

The fair value of the employee retirement plan trust accounts at December 31, 2018 and 2017 was $3.9 million and $3.3 million, respectively. These accounts are invested in cash equivalents and publicly traded mutual funds and are classified as Level 1 assets.

The bonds, employee retirement plan trust accounts, money market funds, mutual funds, and CDs are components of other investments, other special funds, special deposits, and cash in the Balance Sheet.

The fair value of the Company’s long-term debt as of December 31, 2018 and 2017 was $190.0 million and $199.8 million respectively. The fair value of fixed rate long-term debt, which includes the short-term portion, is based on current market quotes which are classified as a Level 1 on the fair value hierarchy at both December 31, 2018 and 2017.

 

The carrying values reported in the Balance Sheet for current assets and liabilities, excluding amounts discussed above, approximate fair value.

 

Additionally, the Company had $10.4 million and $11.0 million at December 31, 2018 and 2017, respectively, in trust related to the post-employment medical benefit plan (see Note 10).

At December 31, 2018 and 2017, these trust assets consist primarily of mutual funds and are classified as Level 1 within the fair value hierarchy.

 

 

10. Employee Benefit Plans

 

The Company maintains a number of employee benefit plans. The description of the plans and key provisions is included below. The plans are included in accumulated provision for pensions and benefits in the Balance Sheet and consist of the following at December 31 (in thousands):

 

[image]

 

Post-employment medical benefit plan

Plan description

The Company sponsors the California ISO Retirees Medical Plan (“the Plan”), a single employer defined benefit plan, to provide post-employment health care benefits to all eligible employees who retire from the Company and meet certain eligibility requirements. The plan was amended in November 2018 effective January 1, 2019. As of January 1, 2019, the plan is closed to new hires and rehires. Additionally, eligibility for retirement was changed to age 55 with at least 10 years of continuous service, whose combined age and years of continuous service equals or exceeds 70. For employees born after January 1, 1969, pre-65 spousal coverage ends on the participants’ 75th birth date. Post-65 spousal coverage is unchanged; a spouse who is removed from pre-65 coverage may obtain coverage once they reach age 65.

 

Depending on years of service, the Company pays between 60% and 70% of the premiums on the coverage elections made by the beneficiaries not to exceed $8,000 per year for individual retiree coverage and $16,000 per year for retiree plus spouse and/or dependent. Plan benefits are available to eligible retirees and to their spouses, domestic partners and eligible dependents, as provided for under the terms of the plan. Current plan coverage extends for the lifetime of the participants and their beneficiaries, except for dependents, which generally terminates at age 26.

The Plan provides a monthly amount per post-65 retiree and eligible post-65 dependents towards the cost of enrolling in any of the Medicare supplemental programs, and at the Company’s discretion, may increase the allowance annually. Supplemental program costs in excess of the provided monthly amount are the responsibility of the retirees and or dependents.

 

There are 552 active employees of which, 91 are fully eligible to retire and 68 retirees, eligible to receive benefits pursuant to the plan as of December 31, 2018.

 

Funding and investment policy

The Company has established a trust for the purposes of funding the plan. The trust was established as a tax-exempt voluntary employees' beneficiary association. All assets of the trust are to be used for the exclusive benefit of the participants and beneficiaries of the plan. Although the Company has fiscal accountability for these assets and holds them in a fiduciary capacity, the assets are not considered assets of the Company and are therefore not included in the Balance Sheet of the Company. The Plan issues audited trust financial statements annually and are available upon request. The trust had the following activity at December 31 (in thousands):

 

 

[image]

 

 

The Company’s current funding policy is to annually contribute an amount such that the total amount in the trust approximates the actuarially determined liability attributable to retirees and their spouses and to active participants who are fully eligible to retire as determined under GASB 75. Based on this current funding policy, the trust is fully funded at December 31, 2018.

 

The Company does not provide funding into the trust related to future obligations associated with employees who have not become eligible to retire, although, as part of its rate structure, the Company collects annual amounts associated with future other post-employment benefit (“OPEB”) obligations for all employees. As a result, assets equivalent to the actuarially determined liability attributable to employees not yet eligible to retire are segregated in a separate custody account. The amounts are adjusted annually to match the current actuarially determined liability.

 

The assets of both the trust and the Company’s segregated funds are invested in accordance with the Board approved California ISO Retirees Medical Plan Investment Policy Statement. In general, the assets are invested in a mix of equity and fixed income mutual funds.

 

The Company also currently funds disbursements for the employer portion of the premiums on the coverage elections made by the pre-65 beneficiaries, their spouse and, if any, dependents, and the monthly contributions to the post-65 retirees and their post-65 dependents from the segregated funds.

 

The plan had the following activity and related accumulated post retirement benefit obligation (“APBO”) at December 31 (in thousands):

[image]

 

 

APBO at December 31, 2018 decreased by $0.6 million primarily due to an actuarial gain of $11.4 million and benefit payments of $0.9 million, partially offset by normal service and interest costs of $3.7 million and to a charge of $7.4 million as a result of amendments to the Plan. In addition, plan assets decreased by $0.7 due to unrealized investment losses during the period. The actuarial gain was primarily the result of the changes in the assumptions including the full adoption of new termination and retirement rates and an increase in the discount rate from 3.7% to 4.3%. The change in the new termination and retirement rates contributed to the majority of the actuarial gain.

 

APBO at December 31, 2017 increased by $3.2 million primarily due to an actuarial loss of $2.0 million and to normal service and interest costs of $3.3 million, partially offset by benefit payments of $0.6 million and to the increase in plan assets of $1.5 million. The actuarial loss was primarily the result of the changes in the assumptions including the full adoption of the latest industry mortality table based on 2017 scales, a change in health care cost assumptions to reflect recent trends in medical costs and a change in the discount rate. The change in the discount rate, which decreased from 4.3% to 3.7% contributed to the majority of the actuarial loss.

 

Actuarial gains or losses and the impact of changes in assumptions are recorded as accumulated other comprehensive income or loss (“AOCI”) in the proprietary capital section of the Balance Sheet. In 2018, the Company recorded a net decrease in AOCI of $2.2 million, which is due to the actuarial gain of $10.1 million mainly resulting from the change in plan assumptions, partially offset by the prior service credit loss of $7.4 million, as a result of plan benefit changes and amortization. In 2017, AOCI increased by $1.5 million for reasons other than amortization. Additionally, the Company amortized $0.6 million and $0.5 million of net prior service credits and net loss, respectively, in 2018 and 2017. The change in the AOCI at December 31 is accounted as follows (in thousands):

 

[image]

 

The significant assumptions that are considered in the calculation of the APBO include the discount rate applied to the estimated future health care benefits (4.3% and 3.7% at December 31, 2018 and 2017, respectively), the expected long-term rate of return on assets assumed in expense was 5.9% for 2018 and 2017 and the estimated costs of the health care premiums to be paid on behalf of the plan beneficiaries. Such estimated costs are based on current premium levels increased by estimated health care cost trend rates over the projected term of the benefits. The health care cost trend rate assumptions used to estimate the actuarial liability as of December 31, 2018, were annual increases of 6.3% in 2019 and 5.0% on the year of the ultimate health care cost trend rate in 2023. The Company estimated the long-term return on plan assets based on historical and future estimated returns.

 

 

 

 

Assumed health care cost trend rates have a significant effect on the benefit obligation amounts reported for the health care plans. A one-percentage-point change in assumed health care cost trend rates would have the following effects (in thousands):

[image]

 

 

A summary of the plan’s postretirement benefit expense for 2018 and 2017 is as follows (in thousands):

 

[image]

The following benefit payments, which reflect expected future health care benefit services, as appropriate, are expected to be paid in connection with the plan as of December 31, 2018 (in thousands):

[image]

 

Executive pension restoration plan

The Company sponsors the Executive Pension Restoration Plan, a non-qualified defined contribution plan, which allows certain officers of the Company to make contributions and receive Company contributions in excess of the 401(k) contribution limits set forth by IRS regulations as described in the retirement savings benefits plan section below.

 

The contributions and earnings thereon are held in a trust and the balances as of December 31, 2018 and 2017, were $2.7 million and $2.3 million, respectively, and are included in Other Assets with a corresponding liability in Employee Retirement Plan Obligations. In connection with this plan, the Company recognized expenses for contributions of $240,000 and $215,000 in 2018 and 2017, respectively.

Executive savings plan

The Company sponsors the Executive Savings Plan, a non-qualified defined contribution plan under section 457(b) of the IRS Code. The Company contributes a percentage of each officer’s annual base compensation to the plan. Officers may elect to make voluntary contributions, subject to statutory limitations.

 

The contributions and earnings thereon are held in a trust and the balance as of December 31, 2018 and 2017 was $1.2 million and $1.0 million, respectively, and are included in Other Assets, with a corresponding liability in Employee Retirement Plan Obligations. In connection with this plan, the Company recognized expenses of $153,700 and $138,000 in 2018 and 2017, respectively.

Retirement savings benefits plan

The Company sponsors a defined contribution retirement plan, the California ISO Retirement Savings Benefits Plan (the “Retirement Plan”) that is subject to the provisions of the Employee Retirement Income Security Act of 1974 and covers substantially all employees. The Retirement Plan is administered by the Company with the assistance of a third party. The assets of the plan are held separately from Company assets and are not combined with the assets in the Balance Sheet.

 

Employees may elect to contribute up to fifty percent of their eligible compensation to the Retirement Plan, subject to statutory limitations. The Company matches contributions up to six percent of an employees’ eligible compensation and an additional contribution equal to five percent of eligible compensation for employees with less than five years of service, or seven percent for employees who have at least five years but not more than ten years of service. An additional contribution of one percent of eligible compensation is also made by the Company for each five year increment of service after an employees’ ten year anniversary.

 

Employee contributions to the Retirement Plan for 2018 and 2017 were $9.3 million and $8.6 million, respectively. The Company contributions to the Retirement Plan for 2018 and 2017 were $9.9 million and $9.7 million, respectively.

 

 

 

 

 

 

 

 

 


11. Insurance Programs and Claims

The Company is exposed to various risks of loss related to torts; theft, damage to, and destruction of assets; errors and omissions; nonperformance of duty; injuries to employees; and natural disasters.  The Company maintains various commercial and mutual insurance plans that provide coverage for most claims in excess of specific dollar thresholds.  Primary insurance policies have coverage limits set based on the Company’s assessment of reasonable exposure within that risk category, with consideration of insurance types and coverage limits for comparable entities.  Additionally, the Company maintains excess liability coverage that provides umbrella coverage for certain exposures.  Losses incurred below insurance deductibles are expensed as incurred.  In the last three years, the Company did not incur any claims in excess of the coverage described above.

The Company is a participant in a group captive insurance company for workers compensation insurance coverage.  The Company’s annual net insurance costs for such coverage vary based on claims incurred at the Company, and to a lesser extent, claims activity of other members of the captive insurance company.  The Company’s annual insurance expense is limited through reinsurance and risk sharing arrangements of the captive to an additional percentage of the initial base premium paid.

 

12. Lease Commitments

 

The Company has long-term operating leases that expire at various times through 2031.

The following are the future minimum payments under these agreements as of December 31, 2018 (in thousands):

 

[image]

 

 

The Company leased office space in Alhambra, which previously served as the backup operations center prior to the relocation, in December 2016, to the facility in Lincoln. The lease expired in August 2017. Although the Company is no longer using the leased space, the Company was required to pay monthly rent through August 2017, and other on-going costs associated with the lease. Lease and service contract costs of approximately $0.2 million were charged to operating expense in 2018 and 2017, respectively.

 


13. Contingencies

 

The Federal Energy Regulatory Commission Refund Case

In 2000 and 2001, the California energy markets, including those managed by the Company, experienced high prices, shortages of energy and reserves, rolling blackouts and liquidity problems for many market participants. Several of them, including the California Power Exchange (Cal PX), filed for bankruptcy.

 

Purchasers of energy during this period sought refunds at the Federal Energy Regulatory Commission. In a proceeding that is still ongoing, the Federal Energy Regulatory Commission has issued a series of orders related to mitigating the clearing prices in markets administered by the Company and the Cal PX for the period from October 2, 2000 through June 20, 2001. Several of the Company’s market participants have settled their liability arising from this case and related proceedings. Management believes the ultimate outcome of the proceeding will have no material financial impact on the Company as these refund amounts are funded and will ultimately be resettled among market participants, except for the Generator Noncompliance Fines, as described in Note 6.

 

Market billing disputes in good faith negotiations

As part of the tariff and applicable contracts, the Company has dispute resolution processes for market participants to register disagreements regarding information reflected in the settlement statements or billing amounts for market activity.

 

Market disputes are addressed in the normal course of operations, some of which result in adjustments to previously issued settlement statements. When adjustments are made the adjustment amounts are reallocated to market participants based on the allocation methodology related to the charge code being adjusted, with no net cost or credit being realized by the Company. With respect to pending market disputes at December 31, 2018, including those that have escalated to good faith negotiations, management believes that any settlements or market adjustments would be resettled against the market with no liability to the Company.

 

Indemnifications  

The Company’s bylaws require its annual financial statements to include disclosures about certain payments made by the Company related to indemnifications to or on behalf of officers and Board members. There were no such payments in 2018 or 2017.

 

Other matters

The Company, during the ordinary course of its operations, has been involved in various lawsuits and claims.  In addition, the Company is subject to compliance requirements of mandatory reliability standards promulgated by the North American Electric Reliability Corporation and approved by the Federal Energy Regulatory Commission, which if violated could result in penalties assessed to the Company.

There are currently some pending claims against the Company as well as matters related to alleged violations of the mandatory reliability standards. Management is of the opinion that none of these matters will have a material adverse impact on the financial position or results of the operations of the Company.

14. Supplemental Cash Flow Information (in thousands)

 

[image]

 

 

15. Subsequent Events

 

The Company has evaluated all subsequent events through April 17, 2019, the date the financial statements were issued, and notes the event below.

 

On January 29, 2019, Pacific Gas & Electric, Corp. (PG&E), one of the Company’s largest customers, filed for bankruptcy reorganization. During these proceedings, PG&E is continuing business operations as normal with the support of $5.5 billion of new financing under arrangements approved by the bankruptcy court. PG&E has paid all market invoices in full and on time, including invoices for pre-petition activity and the Grid Management Charge due to the Company. The Company does not believe there is a risk to its Grid Management Charge even if PG&E were to default on these invoices, because the Company has a priority claim on all market revenue as explained in Note 1.


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
6,548,783
6,548,783
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3
Preceding Quarter/Year to Date Changes in Fair Value
1,671,760
1,671,760
4
Total (lines 2 and 3)
1,671,760
1,671,760
20,347,569
18,675,809
5
Balance of Account 219 at End of Preceding Quarter/Year
8,220,543
8,220,543
6
Balance of Account 219 at Beginning of Current Year
8,220,543
8,220,543
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8
Current Quarter/Year to Date Changes in Fair Value
2,154,146
2,154,146
9
Total (lines 7 and 8)
2,154,146
2,154,146
(a)(b)(c)
7,292,532
9,446,677
10
Balance of Account 219 at End of Current Quarter/Year
6,066,397
6,066,397


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 261 - Schedule - Reconciliation of Reported Net Income with Taxable Income for Federal Income Taxes, Row: 1, Column: b, Value: 0
(b) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 122a - Schedule - Statement of Accumulated Other Comprehensive Income, Comprehensive Income, and Hedging Activities, Row: 9, Column: i, Value: 7292531
(c) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 120 - Schedule - Statement of Cash Flows, Row: 2, Column: b, Value: 7292531

Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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)
641,402,488
641,402,488
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
8
UtilityPlantInServiceClassifiedAndUnclassified
Total (3 thru 7)
641,402,488
641,402,488
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
11
ConstructionWorkInProgress
Construction Work in Progress
16,854,065
16,854,065
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
13
UtilityPlantAndConstructionWorkInProgress
Total Utility Plant (8 thru 12)
658,256,553
658,256,553
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
491,176,799
491,176,799
15
UtilityPlantNet
Net Utility Plant (13 less 14)
167,079,754
167,079,754
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
491,176,799
491,176,799
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
22
DepreciationAmortizationAndDepletionUtilityPlantInService
Total in Service (18 thru 21)
491,176,799
491,176,799
23
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract
Leased to Others
24
DepreciationUtilityPlantLeasedToOthers
Depreciation
25
AmortizationAndDepletionUtilityPlantLeasedToOthers
Amortization and Depletion
26
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers
Total Leased to Others (24 & 25)
27
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract
Held for Future Use
28
DepreciationUtilityPlantHeldForFutureUse
Depreciation
29
AmortizationUtilityPlantHeldForFutureUse
Amortization
30
DepreciationAndAmortizationUtilityPlantHeldForFutureUse
Total Held for Future Use (28 & 29)
31
AbandonmentOfLeases
Abandonment of Leases (Natural Gas)
32
AmortizationOfPlantAcquisitionAdjustment
Amortization of Plant Acquisition Adjustment
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Total Accum Prov (equals 14) (22,26,30,31,32)
491,176,799
491,176,799


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 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
3
(302) Franchise and Consents
4
(303) Miscellaneous Intangible Plant
5
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)
6
2. PRODUCTION PLANT
7
A. Steam Production Plant
8
(310) Land and Land Rights
9
(311) Structures and Improvements
10
(312) Boiler Plant Equipment
11
(313) Engines and Engine-Driven Generators
12
(314) Turbogenerator Units
13
(315) Accessory Electric Equipment
14
(316) Misc. Power Plant Equipment
15
(317) Asset Retirement Costs for Steam Production
16
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
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
28
(331) Structures and Improvements
29
(332) Reservoirs, Dams, and Waterways
30
(333) Water Wheels, Turbines, and Generators
31
(334) Accessory Electric Equipment
32
(335) Misc. Power Plant Equipment
33
(336) Roads, Railroads, and Bridges
34
(337) Asset Retirement Costs for Hydraulic Production
35
TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36
D. Other Production Plant
37
(340) Land and Land Rights
38
(341) Structures and Improvements
39
(342) Fuel Holders, Products, and Accessories
40
(343) Prime Movers
41
(344) Generators
42
(345) Accessory Electric Equipment
43
(346) Misc. Power Plant Equipment
44
(347) Asset Retirement Costs for Other Production
44.1
(348) Energy Storage Equipment - Production
45
TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
46
TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
47
3. Transmission Plant
48
(350) Land and Land Rights
48.1
(351) Energy Storage Equipment - Transmission
49
(352) Structures and Improvements
50
(353) Station Equipment
51
(354) Towers and Fixtures
52
(355) Poles and Fixtures
53
(356) Overhead Conductors and Devices
54
(357) Underground Conduit
55
(358) Underground Conductors and Devices
56
(359) Roads and Trails
57
(359.1) Asset Retirement Costs for Transmission Plant
58
TOTAL Transmission Plant (Enter Total of lines 49 thru 59)
59
4. Distribution Plant
60
(360) Land and Land Rights
61
(361) Structures and Improvements
62
(362) Station Equipment
63
(363) Energy Storage Equipment – Distribution
64
(364) Poles, Towers, and Fixtures
65
(365) Overhead Conductors and Devices
66
(366) Underground Conduit
67
(367) Underground Conductors and Devices
68
(368) Line Transformers
69
(369) Services
70
(370) Meters
71
(371) Installations on Customer Premises
72
(372) Leased Property on Customer Premises
73
(373) Street Lighting and Signal Systems
74
(374) Asset Retirement Costs for Distribution Plant
75
TOTAL Distribution Plant (Enter Total of lines 62 thru 76)
76
5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77
(380) Land and Land Rights
10,561,101
10,561,101
78
(381) Structures and Improvements
161,365,128
151,693
161,516,821
79
(382) Computer Hardware
28,540,096
3,006,405
10,785,039
6,186
20,755,276
80
(383) Computer Software
406,983,396
19,327,570
4,474,412
421,836,554
81
(384) Communication Equipment
12,076,133
213,571
1,457,005
10,832,699
82
(385) Miscellaneous Regional Transmission and Market Operation Plant
15,647,816
259,897
13,863
6,187
15,900,037
83
(386) Asset Retirement Costs for Regional Transmission and Market Oper
84
TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
635,173,670
22,959,136
16,730,319
1
641,402,488
85
6. General Plant
86
(389) Land and Land Rights
87
(390) Structures and Improvements
88
(391) Office Furniture and Equipment
89
(392) Transportation Equipment
90
(393) Stores Equipment
91
(394) Tools, Shop and Garage Equipment
92
(395) Laboratory Equipment
93
(396) Power Operated Equipment
94
(397) Communication Equipment
95
(398) Miscellaneous Equipment
96
SUBTOTAL (Enter Total of lines 86 thru 95)
97
(399) Other Tangible Property
98
(399.1) Asset Retirement Costs for General Plant
99
TOTAL General Plant (Enter Total of lines 96, 97, and 98)
100
TOTAL (Accounts 101 and 106)
635,173,670
22,959,136
16,730,319
1
641,402,488
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)
635,173,670
22,959,136
16,730,319
1
641,402,488


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
Logging System
39,892
2
EMMS Phase 3C
1,405,541
3
EMS Replacement Project
8,701,478
4
ETCC Replacement
969,552
5
Market changes for EMS
192,807
6
CMRI & OASIS Performance Improv
161,917
7
ADS Replacement
79,299
8
CRR Auction Efficiency 1B
406,747
9
Imperial Valley Phase Shifter
1,857
10
Weather and Geospatial Data
228,993
11
ETSR for EMS system
36,125
12
Generator Contingency/RAS Model
376,817
13
R C Services Project
1,692,737
14
Day Ahead Market 15 Min
135,516
15
Commitment Cost & Default Energ
2,450
16
EMNA Functional Enhancements
177,791
17
Load Forecasting Improve for LD
9,523
18
SMUD Sub-BAA
77,431
19
Imbalance Conformace Enh
4,828
20
2017 Hardware Purchases
824,711
21
RC Equipment /Furniture
153,337
22
Seattle City Light
129,088
23
SMUD - EIM
470,975
24
LADWP EIM
170,112
25
Salt River Project EIM
148,828
26
HANA
215,713
27
Lincoln Operations Center
40,000
43
16,854,065


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 11, column (c), and that reported for electric plant in service, pages 204-207, column 9d), 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
472,569,151
472,569,151
2
Depreciation Provisions for Year, Charged to
3
DepreciationExpenseExcludingAdjustments
(403) Depreciation Expense
35,337,967
35,337,967
4
DepreciationExpenseForAssetRetirementCosts
(403.1) Depreciation Expense for Asset Retirement Costs
5
ExpensesOfElectricPlantLeasedToOthers
(413) Exp. of Elec. Plt. Leas. to Others
6
TransportationExpensesClearing
Transportation Expenses-Clearing
7
OtherClearingAccounts
Other Clearing Accounts
8
OtherAccounts
Other Accounts (Specify, details in footnote):
9.1
9.2
9.3
9.4
9.5
10
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)
35,337,967
35,337,967
11
Net Charges for Plant Retired:
12
BookCostOfRetiredPlant
Book Cost of Plant Retired
16,730,319
16,730,319
13
CostOfRemovalOfPlant
Cost of Removal
14
SalvageValueOfRetiredPlant
Salvage (Credit)
15
NetChargesForRetiredPlant
TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)
16,730,319
16,730,319
16
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote):
17.1
17.2
17.3
17.4
17.5
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)
491,176,799
491,176,799
Section B. Balances at End of Year According to Functional Classification
20
AccumulatedDepreciationSteamProduction
Steam Production
21
AccumulatedDepreciationNuclearProduction
Nuclear Production
22
AccumulatedDepreciationHydraulicProductionConventional
Hydraulic Production-Conventional
23
AccumulatedDepreciationHydraulicProductionPumpedStorage
Hydraulic Production-Pumped Storage
24
AccumulatedDepreciationOtherProduction
Other Production
25
AccumulatedDepreciationTransmission
Transmission
26
AccumulatedDepreciationDistribution
Distribution
27
AccumulatedDepreciationRegionalTransmissionAndMarketOperation
Regional Transmission and Market Operation
491,176,799
491,176,799
28
AccumulatedDepreciationGeneral
General
29
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28)
491,176,799
491,176,799


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
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
Total Cost of Account 123.1 $
Total


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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)
2
Fuel Stock Expenses Undistributed (Account 152)
3
Residuals and Extracted Products (Account 153)
4
Plant Materials and Operating Supplies (Account 154)
5
Assigned to - Construction (Estimated)
6
Assigned to - Operations and Maintenance
7
Production Plant (Estimated)
8
Transmission Plant (Estimated)
9
Distribution Plant (Estimated)
10
Regional Transmission and Market Operation Plant (Estimated)
11
Assigned to - Other (provide details in footnote)
12
TOTAL Account 154 (Enter Total of lines 5 thru 11)
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 Lines 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 acquire 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
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
5
Returned by EPA
6
7
8
9
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
19
Other:
20
Allowances Used
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 Lines 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 acquire 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
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
5
Returned by EPA
6
7
8
9
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
19
Other:
20
Allowances Used
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
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
20 TOTAL


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
(a)
40018
143
143
3
40021
143
143
4
40022
143
143
5
40028
429
429
6
40030
47,756
47,756
7
40031
8,412
8,412
8
40032
29,807
29,807
9
40033
874
874
10
40034
7,361
7,361
11
40036
6,128
6,128
12
40037
13
40038
574
574
14
40039
574
574
15
43007
3,015
3,015
16
50010
2,798
2,798
17
50012
286
286
18
50026
1,311
1,311
19
50033
8,111
8,111
20
50039
21
50050
268
268
22
50112
30,727
30,727
23
50144
3,309
3,309
24
50189
2,570
2,570
25
50190
181
181
26
50210
55
55
27
50211
55
55
28
50219
38,790
38,790
29
50246
4,806
4,806
30
50525
1,241
1,241
31
50550
2,156
2,156
32
50556
338
338
33
50569
507
507
34
50571
338
338
35
50630
338
338
36
50647
338
338
37
50666
1,247
1,247
38
50676
4,031
4,031
39
50677
2,894
2,894
40
50702
338
338
41
50711
36
36
42
50713
1,634
1,634
43
50736
1,301
1,301
44
50755
338
338
45
50769
338
338
46
50770
7,344
7,344
47
50773
1,436
1,436
48
50844
41,387
41,387
49
50857
2,274
2,274
50
50880
338
338
51
50887
338
338
52
50892
2,017
2,017
53
50897
606
606
54
50898
169
169
55
51137
2,836
2,836
56
51140
15,546
15,546
57
51142
7,787
7,787
58
51143
8,741
8,741
59
51144
1,617
1,617
60
51145
239
239
61
51146
62
51147
143
143
63
51151
5,118
5,118
64
51152
223
223
65
51154
239
239
66
51155
507
507
67
51156
205
205
68
51158
20,649
20,649
69
51159
268
268
70
51160
411
411
71
51161
3,013
3,013
72
51162
603
603
73
51163
268
268
74
51164
536
536
75
51211
3,742
3,742
76
51219
10,902
10,902
77
51232
2,492
2,492
78
51400
1,547
1,547
79
51409
3,864
3,864
80
51416
1,341
1,341
81
51419
1,021
1,021
82
51421
2,487
2,487
83
51422
338
338
84
51430
169
169
85
51433
512
512
86
51436
6,751
6,751
87
51451
169
169
88
51456
119
119
89
51536
119
119
90
51539
670
670
91
51541
6,582
6,582
92
51544
268
268
93
51551
108
108
94
51552
108
108
95
51555
119
119
96
51556
5,948
5,948
97
51557
5,881
5,881
98
51562
5,881
5,881
99
51565
1,430
1,430
100
51577
1,588
1,588
101
51583
1,236
1,236
102
51589
12
12
103
51590
3,864
3,864
104
51591
3,864
3,864
105
51600
739
739
106
51601
1,713
1,713
107
51602
1,391
1,391
108
51604
1,974
1,974
109
51610
119
119
110
51612
272
272
111
51700
215
215
112
51706
6,197
6,197
113
51707
7,898
7,898
114
51708
9,449
9,449
115
51712
79
79
116
51714
3,021
3,021
117
51715
3,864
3,864
118
51720
3,981
3,981
119
51722
430
430
120
51730
12
12
121
51731
3,981
3,981
122
51732
4,015
4,015
123
51736
1,983
1,983
124
51737
5,854
5,854
125
51742
1,983
1,983
126
51745
9,899
9,899
127
51746
6,160
6,160
128
51747
3,981
3,981
129
51748
3,981
3,981
130
51751
12
12
131
51752
3,323
3,323
132
51753
5,958
5,958
133
51754
1,961
1,961
134
51756
1,983
1,983
135
51757
3,981
3,981
136
51759
2,822
2,822
137
51760
7,400
7,400
138
51761
2,921
2,921
139
51768
3,864
3,864
140
51770
8,486
8,486
141
51772
3,864
3,864
142
51774
3,864
3,864
143
51779
4,196
4,196
144
51783
4,350
4,350
145
51785
3,864
3,864
146
51787
30,463
30,463
147
51791
5,834
5,834
148
51797
149
51798
3,981
3,981
150
51800
6,886
6,886
151
51815
7,554
7,554
152
51817
3,981
3,981
153
51818
7,614
7,614
154
51821
4,353
4,353
155
51822
1,983
1,983
156
51824
3,981
3,981
157
51825
3,981
3,981
158
51826
6,917
6,917
159
51828
3,981
3,981
160
51829
1,983
1,983
161
51904
48,522
48,522
162
51907
23,826
23,826
163
51915
49,816
49,816
164
51916
23,427
23,427
165
51917
49,566
49,566
166
51918
49,778
49,778
167
51919
49,505
49,505
168
51922
82,270
82,270
169
51930
29,116
29,116
170
51935
49,996
49,996
171
51944
172
51948
25,210
25,210
173
51952
49,566
49,566
174
51953
47,984
47,984
175
51954
24,452
24,452
176
51955
23,829
23,829
177
51958
22,019
22,019
178
51959
21,078
21,078
179
51965
25,558
25,558
180
51966
24,645
24,645
181
51967
25,630
25,630
182
51968
22,889
22,889
183
51972
47,445
47,445
184
51973
49,000
49,000
185
51974
22,631
22,631
186
51975
46,013
46,013
187
51978
23,333
23,333
188
51979
25,361
25,361
189
51980
50,211
50,211
190
51982
25,131
25,131
191
51983
27,460
27,460
192
51985
4,077
4,077
193
51988
23,356
23,356
194
51989
46,519
46,519
195
51990
48,456
48,456
196
51994
49,309
49,309
197
51995
23,824
23,824
198
51996
21,556
21,556
199
52004
24,596
24,596
200
52007
24,527
24,527
201
52008
49,996
49,996
202
52009
50,211
50,211
203
52011
48,249
48,249
204
52013
49,529
49,529
205
52017
52,038
52,038
206
52020
45,142
45,142
207
52021
89,576
89,576
208
52022
23,757
23,757
209
52041
529
529
210
52042
529
529
211
52048
529
529
212
52049
529
529
213
52050
529
529
214
52052
529
529
215
52053
529
529
216
52054
529
529
217
52055
529
529
218
52057
529
529
219
52062
647
647
220
52063
529
529
221
52067
529
529
222
52068
529
529
223
52069
529
529
224
53000
40,547
40,547
225
53001
6,577
6,577
226
53002
25,436
25,436
227
53004
46,894
46,894
228
53005
158,167
158,167
229
53008
42,493
42,493
230
53009
45,729
45,729
231
53010
25,773
25,773
232
53011
26,161
26,161
233
53012
28,652
28,652
234
53013
41,122
41,122
235
53014
18,988
18,988
236
53015
43,707
43,707
237
53016
44,483
44,483
238
53017
44,436
44,436
239
53018
34,442
34,442
240
53019
30,647
30,647
241
53020
30,266
30,266
242
53021
29,064
29,064
243
53022
42,481
42,481
244
53023
39,468
39,468
245
53024
47,142
47,142
246
53025
45,343
45,343
247
53026
46,288
46,288
248
53027
42,214
42,214
249
53028
46,241
46,241
250
53029
31,337
31,337
251
53030
44,807
44,807
252
53031
30,968
30,968
253
53032
32,207
32,207
254
53033
30,800
30,800
255
53034
32,977
32,977
256
53035
32,440
32,440
257
53036
28,037
28,037
258
53037
47,369
47,369
259
53038
48,061
48,061
260
53042
44,451
44,451
261
53043
38,782
38,782
262
53044
34,293
34,293
263
53045
39,499
39,499
264
53046
34,084
34,084
265
53047
25,699
25,699
266
53048
44,750
44,750
267
53050
47,550
47,550
268
53051
46,004
46,004
269
53054
30,126
30,126
270
53055
48,074
48,074
271
53057
30,518
30,518
272
53060
48,118
48,118
273
53061
31,709
31,709
274
53063
31,869
31,869
275
53064
47,502
47,502
276
53065
30,486
30,486
277
53066
27,535
27,535
278
53068
30,518
30,518
279
53069
52,645
52,645
280
53070
29,024
29,024
281
53071
46,087
46,087
282
53073
111,217
111,217
283
53074
45,154
45,154
284
53075
46,018
46,018
285
53076
4,798
4,798
286
53077
47,461
47,461
287
53078
45,683
45,683
288
53079
6,071
6,071
289
53080
37,068
37,068
290
53081
40,097
40,097
291
53084
34,157
34,157
292
53085
47,585
47,585
293
53086
45,823
45,823
294
53088
47,866
47,866
295
53089
40,518
40,518
296
53101
11,872
11,872
297
53103
2,921
2,921
298
53104
11,872
11,872
299
53105
3,090
3,090
300
53106
11,872
11,872
301
53107
2,921
2,921
302
53109
3,006
3,006
303
53110
3,006
3,006
304
53112
4,091
4,091
305
53114
2,214
2,214
306
53115
3,090
3,090
307
53117
2,214
2,214
308
53118
2,921
2,921
309
53119
2,921
2,921
310
53120
11,872
11,872
311
53123
11,957
11,957
312
53124
11,957
11,957
313
53125
12,041
12,041
314
53126
2,299
2,299
315
53127
12,041
12,041
316
53128
12,126
12,126
317
53129
2,383
2,383
318
53130
11,957
11,957
319
53131
12,041
12,041
320
53133
2,299
2,299
321
53134
11,957
11,957
322
53135
11,957
11,957
323
53136
2,299
2,299
324
53137
11,957
11,957
325
53138
2,628
2,628
326
53139
12,126
12,126
327
53140
11,872
11,872
328
53141
11,872
11,872
329
53142
1,312
1,312
330
53143
1,312
1,312
331
53150
15,889
15,889
332
53151
18,756
18,756
333
53152
15,152
15,152
334
53154
14,521
14,521
335
53155
11,753
11,753
336
53156
19,975
19,975
337
53157
18,116
18,116
338
53158
8,154
8,154
339
53159
15,522
15,522
340
53160
16,381
16,381
341
53161
13,916
13,916
342
53162
20,735
20,735
343
53163
13,998
13,998
344
53164
17,247
17,247
345
53165
15,298
15,298
346
53166
14,396
14,396
347
53167
15,214
15,214
348
53168
17,446
17,446
349
53169
16,338
16,338
350
53170
19,966
19,966
351
53171
18,968
18,968
352
53172
9,740
9,740
353
53173
18,210
18,210
354
53174
18,505
18,505
355
53175
16,317
16,317
356
53176
10,255
10,255
357
53177
18,827
18,827
358
53178
15,699
15,699
359
53180
17,107
17,107
360
53181
15,195
15,195
361
53182
18,801
18,801
362
53183
14,748
14,748
363
53184
16,297
16,297
364
53186
15,371
15,371
365
53187
17,358
17,358
366
53188
282
282
367
53189
15,870
15,870
368
53190
16,880
16,880
369
53191
17,287
17,287
370
53192
15,032
15,032
371
53193
15,203
15,203
372
53194
16,414
16,414
373
53195
8,625
8,625
374
53196
15,883
15,883
375
53197
17,875
17,875
376
53198
14,182
14,182
377
53199
16,489
16,489
378
53200
15,169
15,169
379
53201
15,716
15,716
380
53202
17,370
17,370
381
53203
17,460
17,460
382
53204
16,091
16,091
383
53205
16,726
16,726
384
53206
8,328
8,328
385
53207
17,996
17,996
386
53208
20,403
20,403
387
53209
16,204
16,204
388
53210
13,978
13,978
389
53211
14,614
14,614
390
53212
13,790
13,790
391
53213
9,061
9,061
392
53214
16,714
16,714
393
53215
18,807
18,807
394
53216
16,887
16,887
395
53218
17,116
17,116
396
53219
9,786
9,786
397
53220
15,911
15,911
398
53221
18,198
18,198
399
53222
19,464
19,464
400
53223
12,437
12,437
401
53224
11,050
11,050
402
53225
13,716
13,716
403
53226
17,767
17,767
404
53228
19,729
19,729
405
53229
16,340
16,340
406
53230
1,746
1,746
407
53231
10,074
10,074
408
53232
8,009
8,009
409
53234
18,981
18,981
410
53235
10,631
10,631
411
53236
16,798
16,798
412
53237
9,335
9,335
413
53238
17,599
17,599
414
53240
15,141
15,141
415
53241
17,632
17,632
416
53244
9,669
9,669
417
53246
3,536
3,536
418
53247
13,117
13,117
419
53249
8,816
8,816
420
53250
7,173
7,173
421
53251
8,964
8,964
422
53252
12,760
12,760
423
53253
9,765
9,765
424
53255
8,549
8,549
425
53256
9,693
9,693
426
53258
13,957
13,957
427
53259
17,176
17,176
428
53261
16,079
16,079
429
53262
15,942
15,942
430
53264
16,766
16,766
431
53265
17,112
17,112
432
53267
15,751
15,751
433
53268
18,329
18,329
434
53270
17,215
17,215
435
53271
18,835
18,835
436
53273
8,560
8,560
437
53274
3,521
3,521
438
53276
17,251
17,251
439
53277
17,647
17,647
440
53279
13,616
13,616
441
53280
13,759
13,759
442
53282
14,308
14,308
443
53283
13,968
13,968
444
53285
14,952
14,952
445
53286
15,115
15,115
446
53288
15,677
15,677
447
53289
19,008
19,008
448
53290
8,618
8,618
449
53295
1,402
1,402
450
53297
3,142
3,142
451
53298
3,142
3,142
452
53299
3,142
3,142
453
53300
3,099
3,099
454
53301
3,099
3,099
455
53303
3,099
3,099
456
53304
3,099
3,099
457
53305
3,099
3,099
458
53306
3,099
3,099
459
53307
3,099
3,099
460
53308
3,099
3,099
461
53309
3,099
3,099
462
53310
3,099
3,099
463
53311
3,057
3,057
464
53312
350
350
465
53313
3,057
3,057
466
53314
3,057
3,057
467
53315
350
350
468
53316
3,057
3,057
469
53317
350
350
470
53318
350
350
471
53319
3,057
3,057
472
53320
3,057
3,057
473
53321
3,057
3,057
474
53322
3,057
3,057
475
53323
3,057
3,057
476
53324
350
350
477
53325
3,057
3,057
478
53326
3,057
3,057
479
53327
3,057
3,057
480
53328
3,057
3,057
481
53329
3,057
3,057
482
53330
3,057
3,057
483
53331
3,057
3,057
484
53332
3,057
3,057
485
53333
3,057
3,057
486
53334
3,057
3,057
487
53335
3,057
3,057
488
53336
3,057
3,057
489
53337
3,057
3,057
490
53338
3,057
3,057
491
53339
350
350
492
53340
3,057
3,057
493
53341
3,057
3,057
494
53342
3,057
3,057
495
53343
3,057
3,057
496
53344
3,057
3,057
497
53345
3,057
3,057
498
53346
3,057
3,057
499
53347
3,057
3,057
500
53348
3,057
3,057
501
53349
350
350
502
53350
350
350
503
53351
3,057
3,057
504
53352
3,057
3,057
505
53353
3,057
3,057
506
53354
3,057
3,057
507
53355
3,057
3,057
508
53356
3,057
3,057
509
53357
3,057
3,057
510
53358
3,057
3,057
511
53359
3,057
3,057
512
53360
3,057
3,057
513
53361
3,057
3,057
514
53362
3,057
3,057
515
53363
3,057
3,057
516
53364
3,057
3,057
517
53365
3,057
3,057
518
53366
3,057
3,057
519
53367
3,057
3,057
520
53368
3,057
3,057
521
53369
3,057
3,057
522
53370
350
350
523
53372
350
350
524
53373
350
350
525
53374
3,057
3,057
526
53375
3,057
3,057
527
53376
3,057
3,057
528
53377
3,057
3,057
529
53378
3,057
3,057
530
53379
3,057
3,057
531
53380
3,057
3,057
532
53381
3,057
3,057
533
53382
1,444
1,444
534
53383
3,057
3,057
535
53385
3,057
3,057
536
53386
3,057
3,057
537
53387
1,444
1,444
538
53388
3,057
3,057
539
53391
3,057
3,057
540
53392
3,057
3,057
541
53393
3,057
3,057
542
53394
2,161
2,161
543
60007
62,314
62,314
544
60025
338
338
545
60049
903
903
546
60052
565
565
547
60061
338
338
548
60089
338
338
549
60117
550
60153
60
60
551
60175
4,695
4,695
552
40013-FT
3,863
3,863
553
50070A
4,355
4,355
554
50127-DS
73
73
555
50212-C
338
338
556
50235-C
169
169
557
50235-DS
73
73
558
50307-C
6,887
6,887
559
50361-C
670
670
560
50370-C
5,334
5,334
561
50558-DS
73
73
562
50569-DS
73
73
563
50594-DS
73
73
564
50598-DS
73
73
565
50642-DS
73
73
566
50743-DS
73
73
567
50754-DS
73
73
568
51056-WD
242
242
569
51133-QM
177
177
570
51135-QM
3,062
3,062
571
60002-FC
196
196
572
60013-FC
332
332
573
60091-FC
60
60
574
60108-FC
60
60
575
60109-FC
60
60
576
60110-FC
60
60
577
60113-FC
332
332
578
60122-FC
332
332
579
60123-C
580
60125-C
60
60
581
60126-C
5,722
5,722
582
60133-FC
60
60
583
60134-FC
60
60
584
60135-FC
60
60
585
60141-C
338
338
586
60147-C
338
338
587
60148-C
60
60
588
60168-C
60
60
589
60192-C
536
536
590
60197-C
60
60
591
60210-C
169
169
592
70003-02
119
119
20
Total
21
Generation Studies
39
Total
40 Grand Total


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfStudyPerformed

The CAISO is completing this schedule to report costs and reimbursements of on-going

generator interconnection studies for the indicated period. Because these studies are in

progress, and due to timing differences between incurring costs and the receipt of

reimbursements, the full amount of costs incurred or reimbursements received on any

particular study may not be fully disclosed on this or subsequent schedules.


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
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
TOTAL


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
Unbilled GIP Receivables
6,393,856
33,970,004
32,840,524
7,523,336
47
Miscellaneous Work in Progress
48
Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49
TOTAL
6,393,856
7,523,336


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
3
4
5
6
7
Other
8 TOTAL Electric (Enter Total of lines 2 thru 7)
9
Other (Specify)
10
11
12
13
14
15
Other
16 TOTAL Gas (Enter Total of lines 10 thru 15)
17 Other (Specify)
18 TOTAL (Acct 190) (Total of lines 8, 16 and 17)
Notes


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
3
4
5
Total
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2019-04-18
Year/Period of Report

End of:
2018
/
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
3
IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders
Increases (Decreases) from Sales of Donations Received from Stockholders
4
DonationsReceivedFromStockholders
Ending Balance Amount
5
ReductionInParOrStatedValueOfCapitalStockAbstract
Reduction in Par or Stated Value of Capital Stock (Account 209)
6
ReductionInParOrStatedValueOfCapitalStock
Beginning Balance Amount
7
IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock
Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8
ReductionInParOrStatedValueOfCapitalStock
Ending Balance Amount
9
GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract
Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10
GainOnResaleOrCancellationOfReacquiredCapitalStock
Beginning Balance Amount
11
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
15
IncreasesDecreasesDueToMiscellaneousPaidInCapital
Increases (Decreases) Due to Miscellaneous Paid-In Capital
16
MiscellaneousPaidInCapital
Ending Balance Amount
17
OtherPaidInCapitalAbstract
Histrocal Data - Other Paid in Capital
18
OtherPaidInCapitalDetail
Beginning Balance Amount
19
IncreasesDecreasesInOtherPaidInCapital
Increases (Decreases) in Other Paid-In Capital
20
OtherPaidInCapitalDetail
Ending Balance Amount
40
OtherPaidInCapital
Total


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
Q4
LONG-TERM DEBT (Account 221, 222, 223 and 224)
  1. Report by Balance Sheet Account the details concerning long-term debt included in Account 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.
  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.
  4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued.
  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 (f). Explain in a footnote any difference between the total of column (f) 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
3
4
5
Subtotal
173,515,000
6
Reacquired Bonds (Account 222)
7
8
9
10
Subtotal
11
Advances from Associated Companies (Account 223)
12
13
14
15
Subtotal
16
Other Long Term Debt (Account 224)
17
18
19
20
Subtotal
Long Term Debt (Historical Data)
1
CIEDB Fixed Rate Revenue Bonds, 2013 Series
191,820,000
10,558,588
(a)
11/14/2013
(b)
02/01/2039
(c)
11/14/2013
(d)
02/01/2039
173,515,000
8,572,717
33 TOTAL
191,820,000
10,558,588
173,515,000
8,572,717


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: NominalDateOfIssue
Original value: 11-14-13
(b) Concept: DateOfMaturity
Original value: 02-01-39
(c) Concept: AmortizationPeriodStartDate
Original value: 11-14-13
(d) Concept: AmortizationPeriodEndDate
Original value: 02-01-39

Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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)
(a)(b)(c)
7,292,532
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
28
Show Computation of Tax:
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 261 - Schedule - Reconciliation of Reported Net Income with Taxable Income for Federal Income Taxes, Row: 1, Column: b, Value: 0
(b) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 122a - Schedule - Statement of Accumulated Other Comprehensive Income, Comprehensive Income, and Hedging Activities, Row: 9, Column: i, Value: 7292531
(c) Concept: NetIncomeLoss
Duplicate fact discrepancy. Schedule: 120 - Schedule - Statement of Cash Flows, Row: 2, Column: b, Value: 7292531

Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 know, 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 then 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 (o) 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
Property Taxes
35,299
35,299
2
FICA
942,612
4,805,139
4,787,664
960,087
3
Medica re
242,388
1,415,990
1,409,685
248,693
4
California Unemployment Tax
86,106
201,251
191,606
95,751
5
Use Tax
1,354
1,354
6
Environmental & Other
182,189
182,189
40
TOTAL
1,271,106
1,304,531


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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%
8 TOTAL
9
Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
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 TOTAL


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
Fines Subject to Refund
2,167,429
464,574
102,375
1,805,230
2
Refund Obligation
3
Unearned Revenue
571,057
571,057
4
Advances for Leasehold Improvemens
5
EIM Implementation Fees
22,490
22,491
1
6
Accrued Taxes
170,267
316,847
146,580
47
TOTAL
2,189,919
1,228,389
990,280
1,951,810


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report


End of:
2018
/
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
5
Other
5.1
Other
5.2
Other
8
TOTAL Electric (Enter Total of lines 3 thru 7)
9
Gas
10
Defense Facilities
11
Pollution Control Facilities
12
Other
12.1
Other
12.2
Other
15
TOTAL Gas (Enter Total of lines 10 thru 14)
16
Other
16.1
Other
16.2
Other
17
TOTAL (Acct 281) (Total of 8, 15 and 16)
18
Classification of TOTAL
19
Federal Income Tax
20
State Income Tax
21
Local Income Tax


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
3
Gas
4
Other (Specify)
5
Total (Total of lines 2 thru 4)
6
7
8
9
TOTAL Account 282 (Total of Lines 5 thru 8)
10
Classification of TOTAL
11
Federal Income Tax
12
State Income Tax
13
Local Income Tax


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 and 277. 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
4
5
6
7
8
9 TOTAL Electric (Total of lines 3 thru 8)
10
Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 TOTAL Other
19 TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)
20
Classification of TOTAL
21
Federal Income Tax
22
State Income Tax
23
Local Income Tax
NOTES


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 pages 108-109, 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
3
CommercialAndIndustrialSalesAbstract
(442) Commercial and Industrial Sales
4
CommercialSalesAbstract
Small (or Comm.) (See Instr. 4)
5
IndustrialSalesAbstract
Large (or Ind.) (See Instr. 4)
6
PublicStreetAndHighwayLightingAbstract
(444) Public Street and Highway Lighting
7
OtherSalesToPublicAuthoritiesAbstract
(445) Other Sales to Public Authorities
8
SalesToRailroadsAndRailwaysAbstract
(446) Sales to Railroads and Railways
9
InterdepartmentalSalesAbstract
(448) Interdepartmental Sales
10
SalesToUltimateConsumersAbstract
TOTAL Sales to Ultimate Consumers
11
SalesForResaleAbstract
(447) Sales for Resale
12
SalesOfElectricityAbstract
TOTAL Sales of Electricity
13
ProvisionForRateRefundsAbstract
(Less) (449.1) Provision for Rate Refunds
14
RevenuesNetOfProvisionForRefundsAbstract
TOTAL Revenues Net of Prov. for Refunds
15
OtherOperatingRevenuesAbstract
Other Operating Revenues
16
ForfeitedDiscounts
(450) Forfeited Discounts
17
MiscellaneousServiceRevenues
(451) Miscellaneous Service Revenues
18
SalesOfWaterAndWaterPower
(453) Sales of Water and Water Power
19
RentFromElectricProperty
(454) Rent from Electric Property
20
InterdepartmentalRents
(455) Interdepartmental Rents
21
OtherElectricRevenue
(456) Other Electric Revenues
22
RevenuesFromTransmissionOfElectricityOfOthers
(456.1) Revenues from Transmission of Electricity of Others
23
RegionalTransmissionServiceRevenues
(457.1) Regional Control Service Revenues
199,400,197
198,307,263
24
MiscellaneousRevenue
(457.2) Miscellaneous Revenues
24,487,716
22,297,787
25
OtherMiscellaneousOperatingRevenues
Other Miscellaneous Operating Revenues
26
OtherOperatingRevenues
TOTAL Other Operating Revenues
223,887,913
220,605,050
27
ElectricOperatingRevenues
TOTAL Electric Operating Revenues
223,887,913
220,605,050


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
GMC Forward Scheduling inter-SC Trades e
502,748
1,063,732
1,758,432
2,356,896
2
GMC Bid Transaction Fee
76,282
162,427
263,656
359,620
3
GMC CRR Transaction Fee
182,818
353,719
564,695
973,929
4
GMC Market Services Charge
12,740,771
26,466,870
43,861,000
57,891,739
5
GMC System Operations Charge
28,597,192
58,875,298
98,164,835
129,697,332
6
GMC CRR Services Charge
779,811
1,508,627
2,303,606
3,100,282
7
GMC Transmission Ownership Rights Charge
212,336
531,604
875,450
1,142,399
8
GMC Scheduling Coordinator ID Charge
914,000
1,871,000
2,872,000
3,878,000
46
TOTAL
44,005,958
90,833,277
150,663,674
199,400,197


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 Pages 310-311.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. 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 - All Accounts
42 TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
43 TOTAL - All Accounts


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 326-327).
  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
2
3
4
5
6
7
8
9
10
11
12
13
14
15
Subtotal - RQ
16
Subtotal-Non-RQ
17 Total


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
5
FuelSteamPowerGeneration
(501) Fuel
6
SteamExpensesSteamPowerGeneration
(502) Steam Expenses
7
SteamFromOtherSources
(503) Steam from Other Sources
8
SteamTransferredCredit
(Less) (504) Steam Transferred-Cr.
9
ElectricExpensesSteamPowerGeneration
(505) Electric Expenses
10
MiscellaneousSteamPowerExpenses
(506) Miscellaneous Steam Power Expenses
11
RentsSteamPowerGeneration
(507) Rents
12
Allowances
(509) Allowances
13
SteamPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 4 thru 12)
14
SteamPowerGenerationMaintenanceAbstract
Maintenance
15
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
(510) Maintenance Supervision and Engineering
16
MaintenanceOfStructuresSteamPowerGeneration
(511) Maintenance of Structures
17
MaintenanceOfBoilerPlantSteamPowerGeneration
(512) Maintenance of Boiler Plant
18
MaintenanceOfElectricPlantSteamPowerGeneration
(513) Maintenance of Electric Plant
19
MaintenanceOfMiscellaneousSteamPlant
(514) Maintenance of Miscellaneous Steam Plant
20
SteamPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 15 thru 19)
21
PowerProductionExpensesSteamPower
TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
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
45
WaterForPower
(536) Water for Power
46
HydraulicExpenses
(537) Hydraulic Expenses
47
ElectricExpensesHydraulicPowerGeneration
(538) Electric Expenses
48
MiscellaneousHydraulicPowerGenerationExpenses
(539) Miscellaneous Hydraulic Power Generation Expenses
49
RentsHydraulicPowerGeneration
(540) Rents
50
HydraulicPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 44 thru 49)
51
HydraulicPowerGenerationContinuedAbstract
C. Hydraulic Power Generation (Continued)
52
HydraulicPowerGenerationMaintenanceAbstract
Maintenance
53
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
(541) Mainentance Supervision and Engineering
54
MaintenanceOfStructuresHydraulicPowerGeneration
(542) Maintenance of Structures
55
MaintenanceOfReservoirsDamsAndWaterways
(543) Maintenance of Reservoirs, Dams, and Waterways
56
MaintenanceOfElectricPlantHydraulicPowerGeneration
(544) Maintenance of Electric Plant
57
MaintenanceOfMiscellaneousHydraulicPlant
(545) Maintenance of Miscellaneous Hydraulic Plant
58
HydraulicPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 53 thru 57)
59
PowerProductionExpensesHydraulicPower
TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60
OtherPowerGenerationAbstract
D. Other Power Generation
61
OtherPowerGenerationOperationAbstract
Operation
62
OperationSupervisionAndEngineeringOtherPowerGeneration
(546) Operation Supervision and Engineering
63
Fuel
(547) Fuel
64
GenerationExpenses
(548) Generation Expenses
64.1
OperationOfEnergyStorageEquipment
(548.1) Operation of Energy Storage Equipment
65
MiscellaneousOtherPowerGenerationExpenses
(549) Miscellaneous Other Power Generation Expenses
66
RentsOtherPowerGeneration
(550) Rents
67
OtherPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 62 thru 67)
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
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)
74
PowerProductionExpensesOtherPower
TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
75
OtherPowerSuplyExpensesAbstract
E. Other Power Supply Expenses
76
PurchasedPower
(555) Purchased Power
76.1
PowerPurchasedForStorageOperations
(555.1) Power Purchased for Storage Operations
77
SystemControlAndLoadDispatchingElectric
(556) System Control and Load Dispatching
78
OtherExpensesOtherPowerSupplyExpenses
(557) Other Expenses
79
OtherPowerSupplyExpense
TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)
80
PowerProductionExpenses
TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)
81
TransmissionExpensesAbstract
2. TRANSMISSION EXPENSES
82
TransmissionExpensesOperationAbstract
Operation
83
OperationSupervisionAndEngineeringElectricTransmissionExpenses
(560) Operation Supervision and Engineering
5,265,204
4,705,346
85
LoadDispatchReliability
(561.1) Load Dispatch-Reliability
9,179,202
6,292,733
86
LoadDispatchMonitorAndOperateTransmissionSystem
(561.2) Load Dispatch-Monitor and Operate Transmission System
8,256,011
8,738,898
87
LoadDispatchTransmissionServiceAndScheduling
(561.3) Load Dispatch-Transmission Service and Scheduling
7,050,830
7,809,519
88
SchedulingSystemControlAndDispatchServices
(561.4) Scheduling, System Control and Dispatch Services
89
ReliabilityPlanningAndStandardsDevelopment
(561.5) Reliability, Planning and Standards Development
9,732,525
9,417,891
90
TransmissionServiceStudies
(561.6) Transmission Service Studies
91
GenerationInterconnectionStudies
(561.7) Generation Interconnection Studies
3,426,699
3,386,778
92
ReliabilityPlanningAndStandardsDevelopmentServices
(561.8) Reliability, Planning and Standards Development Services
93
StationExpensesTransmissionExpense
(562) Station Expenses
93.1
OperationOfEnergyStorageEquipmentTransmissionExpense
(562.1) Operation of Energy Storage Equipment
94
OverheadLineExpense
(563) Overhead Lines Expenses
95
UndergroundLineExpensesTransmissionExpense
(564) Underground Lines Expenses
96
TransmissionOfElectricityByOthers
(565) Transmission of Electricity by Others
97
MiscellaneousTransmissionExpenses
(566) Miscellaneous Transmission Expenses
98
RentsTransmissionElectricExpense
(567) Rents
99
TransmissionOperationExpense
TOTAL Operation (Enter Total of Lines 83 thru 98)
42,910,471
40,351,165
100
TransmissionMaintenanceAbstract
Maintenance
101
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses
(568) Maintenance Supervision and Engineering
10,902,091
9,747,374
102
MaintenanceOfStructuresTransmissionExpense
(569) Maintenance of Structures
103
MaintenanceOfComputerHardwareTransmission
(569.1) Maintenance of Computer Hardware
104
MaintenanceOfComputerSoftwareTransmission
(569.2) Maintenance of Computer Software
105
MaintenanceOfCommunicationEquipmentElectricTransmission
(569.3) Maintenance of Communication Equipment
106
MaintenanceOfMiscellaneousRegionalTransmissionPlant
(569.4) Maintenance of Miscellaneous Regional Transmission Plant
107
MaintenanceOfStationEquipmentTransmission
(570) Maintenance of Station Equipment
107.1
MaintenanceOfEnergyStorageEquipmentTransmission
(570.1) Maintenance of Energy Storage Equipment
108
MaintenanceOfOverheadLinesTransmission
(571) Maintenance of Overhead Lines
109
MaintenanceOfUndergroundLinesTransmission
(572) Maintenance of Underground Lines
110
MaintenanceOfMiscellaneousTransmissionPlant
(573) Maintenance of Miscellaneous Transmission Plant
111
TransmissionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 101 thru 110)
10,902,091
9,747,374
112
TransmissionExpenses
TOTAL Transmission Expenses (Total of Lines 99 and 111)
53,812,562
50,098,539
113
RegionalMarketExpensesAbstract
3. REGIONAL MARKET EXPENSES
114
RegionalMarketExpensesOperationAbstract
Operation
115
OperationSupervision
(575.1) Operation Supervision
10,772,370
10,872,046
116
DayAheadAndRealTimeMarketAdministration
(575.2) Day-Ahead and Real-Time Market Facilitation
6,519,941
5,941,667
117
TransmissionRightsMarketAdministration
(575.3) Transmission Rights Market Facilitation
118
CapacityMarketAdministration
(575.4) Capacity Market Facilitation
119
AncillaryServicesMarketAdministration
(575.5) Ancillary Services Market Facilitation
220,097
568,780
120
MarketMonitoringAndCompliance
(575.6) Market Monitoring and Compliance
7,041,275
6,790,125
121
MarketFacilitationMonitoringAndComplianceServices
(575.7) Market Facilitation, Monitoring and Compliance Services
122
RentsRegionalMarketExpenses
(575.8) Rents
123
RegionalMarketOperationExpense
Total Operation (Lines 115 thru 122)
24,553,683
24,172,618
124
RegionalMarketExpensesMaintenanceAbstract
Maintenance
125
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses
(576.1) Maintenance of Structures and Improvements
126
MaintenanceOfComputerHardware
(576.2) Maintenance of Computer Hardware
1,726,005
2,166,953
127
MaintenanceOfComputerSoftware
(576.3) Maintenance of Computer Software
5,180,718
4,804,845
128
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses
(576.4) Maintenance of Communication Equipment
4,408,102
4,548,387
129
MaintenanceOfMiscellaneousMarketOperationPlant
(576.5) Maintenance of Miscellaneous Market Operation Plant
130
RegionalMarketMaintenanceExpense
Total Maintenance (Lines 125 thru 129)
11,314,825
11,520,185
131
RegionalMarketExpenses
TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)
35,868,508
35,692,803
132
DistributionExpensesAbstract
4. DISTRIBUTION EXPENSES
133
DistributionExpensesOperationAbstract
Operation
134
OperationSupervisionAndEngineeringDistributionExpense
(580) Operation Supervision and Engineering
135
LoadDispatching
(581) Load Dispatching
136
StationExpensesDistribution
(582) Station Expenses
137
OverheadLineExpenses
(583) Overhead Line Expenses
138
UndergroundLineExpenses
(584) Underground Line Expenses
138.1
OperationOfEnergyStorageEquipmentDistribution
(584.1) Operation of Energy Storage Equipment
139
StreetLightingAndSignalSystemExpenses
(585) Street Lighting and Signal System Expenses
140
MeterExpenses
(586) Meter Expenses
141
CustomerInstallationsExpenses
(587) Customer Installations Expenses
142
MiscellaneousDistributionExpenses
(588) Miscellaneous Expenses
143
RentsDistributionExpense
(589) Rents
144
DistributionOperationExpensesElectric
TOTAL Operation (Enter Total of Lines 134 thru 143)
145
DistributionExpensesMaintenanceAbstract
Maintenance
146
MaintenanceSupervisionAndEngineering
(590) Maintenance Supervision and Engineering
147
MaintenanceOfStructuresDistributionExpense
(591) Maintenance of Structures
148
MaintenanceOfStationEquipment
(592) Maintenance of Station Equipment
148.1
MaintenanceOfEnergyStorageEquipment
(592.2) Maintenance of Energy Storage Equipment
149
MaintenanceOfOverheadLines
(593) Maintenance of Overhead Lines
150
MaintenanceOfUndergroundLines
(594) Maintenance of Underground Lines
151
MaintenanceOfLineTransformers
(595) Maintenance of Line Transformers
152
MaintenanceOfStreetLightingAndSignalSystems
(596) Maintenance of Street Lighting and Signal Systems
153
MaintenanceOfMeters
(597) Maintenance of Meters
154
MaintenanceOfMiscellaneousDistributionPlant
(598) Maintenance of Miscellaneous Distribution Plant
155
DistributionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 146 thru 154)
156
DistributionExpenses
TOTAL Distribution Expenses (Total of Lines 144 and 155)
157
CustomerAccountsExpensesAbstract
5. CUSTOMER ACCOUNTS EXPENSES
158
CustomerAccountsExpensesOperationsAbstract
Operation
159
SupervisionCustomerAccountExpenses
(901) Supervision
160
MeterReadingExpenses
(902) Meter Reading Expenses
110,050
284,390
161
CustomerRecordsAndCollectionExpenses
(903) Customer Records and Collection Expenses
7,832,155
7,183,421
162
UncollectibleAccounts
(904) Uncollectible Accounts
163
MiscellaneousCustomerAccountsExpenses
(905) Miscellaneous Customer Accounts Expenses
90,000
164
CustomerAccountExpenses
TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)
7,942,205
7,557,811
165
CustomerServiceAndInformationalExpensesAbstract
6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166
CustomerServiceAndInformationalExpensesOperationAbstract
Operation
167
SupervisionCustomerServiceAndInformationExpenses
(907) Supervision
42,704
168
CustomerAssistanceExpenses
(908) Customer Assistance Expenses
4,869,355
4,486,509
169
InformationalAndInstructionalAdvertisingExpenses
(909) Informational and Instructional Expenses
170
MiscellaneousCustomerServiceAndInformationalExpenses
(910) Miscellaneous Customer Service and Informational Expenses
1,697,608
1,437,610
171
CustomerServiceAndInformationExpenses
TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)
6,566,963
5,966,823
172
SalesExpenseAbstract
7. SALES EXPENSES
173
SalesExpenseOperationAbstract
Operation
174
SupervisionSalesExpense
(911) Supervision
175
DemonstratingAndSellingExpenses
(912) Demonstrating and Selling Expenses
176
AdvertisingExpenses
(913) Advertising Expenses
177
MiscellaneousSalesExpenses
(916) Miscellaneous Sales Expenses
178
SalesExpenses
TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
179
AdministrativeAndGeneralExpensesAbstract
8. ADMINISTRATIVE AND GENERAL EXPENSES
180
AdministrativeAndGeneralExpensesOperationAbstract
Operation
181
AdministrativeAndGeneralSalaries
(920) Administrative and General Salaries
46,431,819
44,547,998
182
OfficeSuppliesAndExpenses
(921) Office Supplies and Expenses
2,369,976
2,061,707
183
AdministrativeExpensesTransferredCredit
(Less) (922) Administrative Expenses Transferred-Credit
184
OutsideServicesEmployed
(923) Outside Services Employed
11,449,804
10,703,396
185
PropertyInsurance
(924) Property Insurance
1,914,232
1,985,011
186
InjuriesAndDamages
(925) Injuries and Damages
500
187
EmployeePensionsAndBenefits
(926) Employee Pensions and Benefits
188
FranchiseRequirements
(927) Franchise Requirements
189
RegulatoryCommissionExpenses
(928) Regulatory Commission Expenses
1,229,615
1,264,591
190
DuplicateChargesCredit
(929) (Less) Duplicate Charges-Cr.
191
GeneralAdvertisingExpenses
(930.1) General Advertising Expenses
41,884
40,577
192
MiscellaneousGeneralExpenses
(930.2) Miscellaneous General Expenses
1,010,840
917,975
193
RentsAdministrativeAndGeneralExpense
(931) Rents
88,205
95,776
194
AdministrativeAndGeneralOperationExpense
TOTAL Operation (Enter Total of Lines 181 thru 193)
64,536,375
61,617,531
195
AdministrativeAndGeneralExpensesMaintenanceAbstract
Maintenance
196
MaintenanceOfGeneralPlant
(935) Maintenance of General Plant
6,424,638
6,328,321
197
AdministrativeAndGeneralExpenses
TOTAL Administrative & General Expenses (Total of Lines 194 and 196)
70,961,013
67,945,852
198
OperationsAndMaintenanceExpensesElectric
TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)
175,151,251
167,261,828


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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. 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 column (g) through (n) must be totalled on the last line of the schedule. The total amount in column (g) 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
2
3
4
5
6
7
8
9
10
11
12
13
14
15 TOTAL


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 (11011) 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
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 TOTAL


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
San Diego Gas & Electric.
384 HV Wheeling Revenue
9,793,262
2
San Diego Gas & Electric Co.
374 HV Access Revenue
497,999,862
3
507,793,124
4
Southern California Edison Co.
374 HV Access Revenue
1,036,490,814
5
Southern California Edison Co.
385 LV Wheeling Revenue
10,512,562
6
Southern California Edison Co.
384 HV Wheeling Revenue
42,951,116
7
1,089,954,492
8
Pacific Gas & Electric Com
374 HV Access Revenue
594,329,209
9
Pacific Gas & Electric Com
384 HV Wheeling Revenue
139,760,528
10
Pacific Gas & Electric Com
385 LV Wheeling Revenue
65,568,067
11
799,657,804
12
City of Azusa - PTO
374 HV Access Revenue
955,198
13
City of Azusa - PTO
384 HV Wheeling Revenue
277,494
14
1,232,692
15
City of Banning - PTO
374 HV Access Revenue
969,425
16
City of Banning - PTO
384 HV Wheeling Revenue
1,783
17
971,208
18
City of Anaheim - PTO
374 HV Access Revenue
28,740,266
19
City of Anaheim - PTO
384 HV Wheeling Revenue
20,356
20
28,760,622
21
City of Vernon - PTO
374 HV Access Revenue
2,804,962
22
City of Vernon - PTO
384 HV Wheeling Revenue
5,401
23
2,810,363
24
City of Riverside - PTO
374 HV Access Revenue
35,669,805
25
City of Riverside - PTO
384 HV Wheeling Revenue
16,969
26
35,686,774
27
City of Pasadena - PTO
374 HV Access Revenue
14,587,948
28
City of Pasadena - PTO
384 HV Wheeling Revenue
19,006
29
14,606,954
30
DATC Path 15, LLC
374 HV Access Revenue
25,561,555
31
25,561,555
32
STARTRANS IO, LLC
374 HV Access Revenue
3,305,473
33
STARTRANS IO, LLC
384 HV Wheeling Revenue
908
34
3,306,381
35
Trans Bay Cable, LLC
374 HV Access Revenue
125,149,747
36
125,149,747
37
Citizens Sunrise Transmission LLC
374 HV Access Revenue
12,623,449
38
12,623,449
39
Valley Electric Association, Inc.-PTO
384 HV Wheeling Revenue
137,733
40
137,733
41
City of Colton-TO18
374 HV Access Revenue
1,452,362
42
City of Colton-TO18
384 HV Wheeling Revenue
163
43
1,452,525
44
GridLiance West Transco LLC -TO19
384 HV Wheeling Revenue
790,613
45
GridLiance West Transco LLC -TO19
374 HV Access Revenue
19,627,322
46
20,417,935
40
TOTAL
2,670,123,358
2,670,123,358


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
TOTAL


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
Q4
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.
Description
(a)
Amount
(b)
1
IndustryAssociationDues
Industry Association Dues
2
NuclearPowerResearchExpenses
Nuclear Power Research Expenses
3
OtherExperimentalAndGeneralResearchExpenses
Other Experimental and General Research Expenses
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
Bank Service Fee
300,046
7
Board of Directors Fees and Expense
710,794
46
MiscellaneousGeneralExpenses
TOTAL
1,010,840


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 8 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 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
2
Steam Production Plant
3
Nuclear Production Plant
4
Hydraulic Production Plant-Conventional
5
Hydraulic Production Plant-Pumped Storage
6
Other Production Plant
7
Transmission Plant
8
Distribution Plant
9
Regional Transmission and Market Operation
35,337,967
35,337,967
10
General Plant
11
Common Plant-Electric
12
TOTAL
35,337,967
35,337,967
B. Basis for Amortization Charges
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
0 years
0 years
13
0 years
0 years
14
0 years
0 years
15
0 years
0 years
16
0 years
0 years
17
0 years
0 years
18
0 years
0 years
19
0 years
0 years
20
10,561,100
(a)
1 year
0 years
21
107,072,130
(b)
24 years
4.24
(g)
14 years
22
3,561,018
(c)
3 years
30.52
(h)
3 years
23
23,020,689
(d)
5 years
19.96
(i)
1 year
24
3,241,260
(e)
6 years
15.55
(j)
3 years
25
2,769,491
(f)
7 years
13.34
(k)
3 years


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: UtilityPlantEstimatedAverageServiceLife
Original value: 1
(b) Concept: UtilityPlantEstimatedAverageServiceLife
Original value: 23.56
(c) Concept: UtilityPlantEstimatedAverageServiceLife
Original value: 3.28
(d) Concept: UtilityPlantEstimatedAverageServiceLife
Original value: 5.01
(e) Concept: UtilityPlantEstimatedAverageServiceLife
Original value: 6.43
(f) Concept: UtilityPlantEstimatedAverageServiceLife
Original value: 7.49
(g) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 14.35
(h) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2.56
(i) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 0.94
(j) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 3.4
(k) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2.75

Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 column (f), (g), and (h) expenses incurred during 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
EXPENSES INCURRED DURING YEAR
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)
RegulatoryCommissionExpenses
Amount
(h)
RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets
Deferred to Account 182.3
(i)
DeferredRegulatoryCommissionExpensesAmortizedInContraAccount
Contra Account
(j)
DeferredRegulatoryCommissionExpensesAmortized
Amount
(k)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred to Account 182.3 End of Year
(l)
1
FERC Hearings
1,229,615
1,229,615
GenCounsel
1,229,615
46
TOTAL
1,229,615
1,229,615
1,229,615


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
4
SalariesAndWagesElectricOperationTransmission
Transmission
41,548,103
5
SalariesAndWagesElectricOperationRegionalMarket
Regional Market
22,676,345
6
SalariesAndWagesElectricOperationDistribution
Distribution
7
SalariesAndWagesElectricOperationCustomerAccounts
Customer Accounts
8,030,636
8
SalariesAndWagesElectricOperationCustomerServiceAndInformational
Customer Service and Informational
5,855,405
9
SalariesAndWagesElectricOperationSales
Sales
10
SalariesAndWagesElectricOperationAdministrativeAndGeneral
Administrative and General
45,873,932
11
SalariesAndWagesElectricOperation
TOTAL Operation (Enter Total of lines 3 thru 10)
123,984,421
12
SalariesAndWagesElectricMaintenanceAbstract
Maintenance
13
SalariesAndWagesElectricMaintenanceProduction
Production
14
SalariesAndWagesElectricMaintenanceTransmission
Transmission
1,730,280
15
SalariesAndWagesElectricMaintenanceRegionalMarket
Regional Market
1,997,373
16
SalariesAndWagesElectricMaintenanceDistribution
Distribution
17
SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral
Administrative and General
18
SalariesAndWagesElectricMaintenance
TOTAL Maintenance (Total of lines 13 thru 17)
3,727,653
19
SalariesAndWagesElectricOperationAndMaintenanceAbstract
Total Operation and Maintenance
20
SalariesAndWagesElectricProduction
Production (Enter Total of lines 3 and 13)
21
SalariesAndWagesElectricTransmission
Transmission (Enter Total of lines 4 and 14)
43,278,383
22
SalariesAndWagesElectricRegionalMarket
Regional Market (Enter Total of Lines 5 and 15)
24,673,718
23
SalariesAndWagesElectricDistribution
Distribution (Enter Total of lines 6 and 16)
24
SalariesAndWagesElectricCustomerAccounts
Customer Accounts (Transcribe from line 7)
8,030,636
25
SalariesAndWagesElectricCustomerServiceAndInformational
Customer Service and Informational (Transcribe from line 8)
5,855,405
26
SalariesAndWagesElectricSales
Sales (Transcribe from line 9)
27
SalariesAndWagesElectricAdministrativeAndGeneral
Administrative and General (Enter Total of lines 10 and 17)
45,873,932
28
SalariesAndWagesElectricOperationAndMaintenance
TOTAL Oper. and Maint. (Total of lines 20 thru 27)
127,712,074
127,712,074
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)
38
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational (Line 38)
39
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)
127,712,074
127,712,074
66
SalariesAndWagesUtilityPlantAbstract
Utility Plant
67
SalariesAndWagesUtilityPlantConstructionAbstract
Construction (By Utility Departments)
68
SalariesAndWagesUtilityPlantConstructionElectricPlant
Electric Plant
69
SalariesAndWagesUtilityPlantConstructionGasPlant
Gas Plant
70
SalariesAndWagesUtilityPlantConstructionOther
Other (provide details in footnote):
71
SalariesAndWagesUtilityPlantConstruction
TOTAL Construction (Total of lines 68 thru 70)
72
SalariesAndWagesPlantRemovalAbstract
Plant Removal (By Utility Departments)
73
SalariesAndWagesPlantRemovalElectricPlant
Electric Plant
74
SalariesAndWagesPlantRemovalGasPlant
Gas Plant
75
SalariesAndWagesPlantRemovalOther
Other (provide details in footnote):
76
SalariesAndWagesPlantRemoval
TOTAL Plant Removal (Total of lines 73 thru 75)
77
SalariesAndWagesOtherAccountsAbstract
Other Accounts (Specify, provide details in footnote):
78
SalariesAndWagesOtherAccountsDescription
79
SalariesAndWagesOtherAccountsDescription
80
SalariesAndWagesOtherAccountsDescription
81
SalariesAndWagesOtherAccountsDescription
82
SalariesAndWagesOtherAccountsDescription
83
SalariesAndWagesOtherAccountsDescription
84
SalariesAndWagesOtherAccountsDescription
85
SalariesAndWagesOtherAccountsDescription
86
SalariesAndWagesOtherAccountsDescription
87
SalariesAndWagesOtherAccountsDescription
88
SalariesAndWagesOtherAccountsDescription
89
SalariesAndWagesOtherAccountsDescription
90
SalariesAndWagesOtherAccountsDescription
91
SalariesAndWagesOtherAccountsDescription
92
SalariesAndWagesOtherAccountsDescription
93
SalariesAndWagesOtherAccountsDescription
94
SalariesAndWagesOtherAccountsDescription
95
SalariesAndWagesOtherAccounts
TOTAL Other Accounts
96
SalariesAndWagesGeneralExpense
TOTAL SALARIES AND WAGES
127,712,074
127,712,074


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 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 order of the Commission or other authorization.


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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)
2.1 Net Purchases (Account 555.1)
3 Net Sales (Account 447)
4 Transmission Rights
5 Ancillary Services
6 Other Items (list separately)
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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: EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0
1
January
2
February
3
March
4
Total for Quarter 1
5
April
6
May
7
June
8
Total for Quarter 2
9
July
10
August
11
September
12
Total for Quarter 3
13
October
14
November
15
December
16
Total for Quarter 4
17
Total


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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: EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G-0
1
January
28,803
29
1,900
7,461,965
89,949
941,660
6,430,356
2
February
28,891
20
1,900
6,155,303
101,873
741,246
5,312,184
3
March
27,742
1
1,900
6,374,696
43,833
719,303
5,611,560
4
Total for Quarter 1
19,991,964
235,655
2,402,209
17,354,100
5
April
29,256
9
2,000
5,242,424
23,807
735,480
4,483,137
6
May
32,189
29
1,800
6,587,766
37,808
900,553
5,649,405
7
June
37,442
22
1,800
7,169,435
42,078
1,002,480
6,124,877
8
Total for Quarter 2
18,999,625
103,693
2,638,513
16,257,419
9
July
46,425
24
1,800
6,731,052
65,518
989,505
5,676,029
10
August
45,003
9
1,700
6,836,808
45,434
907,806
5,883,568
11
September
38,310
7
1,700
6,221,519
44,639
827,368
5,349,512
12
Total for Quarter 3
19,789,379
155,591
2,724,679
16,909,109
13
October
34,272
1
1,700
5,186,250
71,853
671,677
4,442,720
14
November
28,993
14
1,800
5,095,923
196,026
693,586
4,206,311
15
December
29,999
5
1,800
6,162,237
251,223
752,834
5,158,180
16
Total for Quarter 4
16,444,410
519,102
2,118,097
13,807,211
17
Total Year to Date/Year
75,225,378
1,014,041
9,883,498
64,327,839


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2019-04-18
Year/Period of Report

End of:
2018
/
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)
3
Steam
23
Requirements Sales for Resale (See instruction 4, page 311.)
4
Nuclear
24
Non-Requirements Sales for Resale (See instruction 4, page 311.)
5
Hydro-Conventional
25
Energy Furnished Without Charge
6
Hydro-Pumped Storage
26
Energy Used by the Company (Electric Dept Only, Excluding Station Use)
7
Other
27
Total Energy Losses
8
Less Energy for Pumping
27.1
Total Energy Stored
9
Net Generation (Enter Total of lines 3 through 8)
28
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES
10
Purchases (other than for Energy Storage)
10.1
Purchases for Energy Storage
11
Power Exchanges:
12
Received
13
Delivered
14
Net Exchanges (Line 12 minus line 13)
15
Transmission For Other (Wheeling)
16
Received
17
Delivered
18
Net Transmission for Other (Line 16 minus line 17)
19
Transmission By Others Losses
20
TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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: EDRP (for Imports, Exports, Wheels), ALFS_MRTU (for total G
29
January
17,579,282
28,803
29
1,900
30
February
15,584,880
28,891
20
1,900
31
March
16,861,195
27,742
1
1,900
32
April
16,196,649
29,256
9
2,000
33
May
17,566,607
32,189
29
1,800
34
June
18,946,717
37,442
22
1,800
35
July
23,996,991
46,425
24
1,800
36
August
23,525,773
45,003
9
1,700
37
September
19,606,522
38,310
7
1,700
38
October
18,010,227
34,272
1
1,700
39
November
16,984,535
28,993
14
1,800
40
December
17,938,152
29,999
5
1,800
41
Total


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 U. S. of A. 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:
Plant Name:
1
PlantKind
Kind of Plant (Internal Comb, Gas Turb, Nuclear)
2
PlantConstructionType
Type of Constr (Conventional, Outdoor, Boiler, etc)
3
YearPlantOriginallyConstructed
Year Originally Constructed
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
5
InstalledCapacityOfPlant
Total Installed Cap (Max Gen Name Plate Ratings-MW)
6
NetPeakDemandOnPlant
Net Peak Demand on Plant - MW (60 minutes)
7
PlantHoursConnectedToLoad
Plant Hours Connected to Load
8
NetContinuousPlantCapability
Net Continuous Plant Capability (Megawatts)
9
NetContinuousPlantCapabilityNotLimitedByCondenserWater
When Not Limited by Condenser Water
10
NetContinuousPlantCapabilityLimitedByCondenserWater
When Limited by Condenser Water
11
PlantAverageNumberOfEmployees
Average Number of Employees
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - KWh
13
CostOfLandAndLandRightsSteamProduction
Cost of Plant: Land and Land Rights
14
CostOfStructuresAndImprovementsSteamProduction
Structures and Improvements
15
CostOfEquipmentSteamProduction
Equipment Costs
16
AssetRetirementCostsSteamProduction
Asset Retirement Costs
17
CostOfPlant
Total cost (total 13 thru 20)
18
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 17/5) Including
19
OperationSupervisionAndEngineeringExpense
Production Expenses: Oper, Supv, & Engr
20
FuelSteamPowerGeneration
Fuel
21
CoolantsAndWater
Coolants and Water (Nuclear Plants Only)
22
SteamExpensesSteamPowerGeneration
Steam Expenses
23
SteamFromOtherSources
Steam From Other Sources
24
SteamTransferredCredit
Steam Transferred (Cr)
25
ElectricExpensesSteamPowerGeneration
Electric Expenses
26
MiscellaneousSteamPowerExpenses
Misc Steam (or Nuclear) Power Expenses
27
RentsSteamPowerGeneration
Rents
28
Allowances
Allowances
29
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
Maintenance Supervision and Engineering
30
MaintenanceOfStructuresSteamPowerGeneration
Maintenance of Structures
31
MaintenanceOfBoilerPlantSteamPowerGeneration
Maintenance of Boiler (or reactor) Plant
32
MaintenanceOfElectricPlantSteamPowerGeneration
Maintenance of Electric Plant
33
MaintenanceOfMiscellaneousSteamPlant
Maintenance of Misc Steam (or Nuclear) Plant
34
PowerProductionExpensesSteamPower
Total Production Expenses
35
ExpensesPerNetKilowattHour
Expenses per Net KWh
35
FuelKindAxis
Plant Name
36
FuelKind
Fuel Kind
37
FuelUnit
Fuel Unit
38
QuantityOfFuelBurned
Quantity (Units) of Fuel Burned
39
FuelBurnedAverageHeatContent
Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
40
AverageCostOfFuelPerUnitAsDelivered
Avg Cost of Fuel/unit, as Delvd f.o.b. during year
41
AverageCostOfFuelPerUnitBurned
Average Cost of Fuel per Unit Burned
42
AverageCostOfFuelBurnedPerMillionBritishThermalUnit
Average Cost of Fuel Burned per Million BTU
43
AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Average Cost of Fuel Burned per KWh Net Gen
44
AverageBritishThermalUnitPerKilowattHourNetGeneration
Average BTU per KWh Net Generation


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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.
Plant Name:
FERC Licensed Project No.
Plant Name:
FERC Licensed Project No.
Plant Name:
FERC Licensed Project No.
Plant Name:
FERC Licensed Project No.
Plant Name:
1
PlantKind
Kind of Plant (Run-of-River or Storage)
2
PlantConstructionType
Plant Construction type (Conventional or Outdoor)
3
YearPlantOriginallyConstructed
Year Originally Constructed
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
5
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
6
NetPeakDemandOnPlant
Net Peak Demand on Plant-Megawatts (60 minutes)
7
PlantHoursConnectedToLoad
Plant Hours Connect to Load
8
NetPlantCapabilityAbstract
Net Plant Capability (in megawatts)
9
NetPlantCapabilityUnderMostFavorableOperatingConditions
(a) Under Most Favorable Oper Conditions
10
NetPlantCapabilityUnderMostAdverseOperatingConditions
(b) Under the Most Adverse Oper Conditions
11
PlantAverageNumberOfEmployees
Average Number of Employees
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - Kwh
13
CostOfPlantAbstract
Cost of Plant
14
CostOfLandAndLandRightsHydroelectricProduction
Land and Land Rights
15
CostOfStructuresAndImprovementsHydroelectricProduction
Structures and Improvements
16
CostOfReservoirsDamsAndWaterwaysHydroelectricProduction
Reservoirs, Dams, and Waterways
17
EquipmentCostsHydroelectricProduction
Equipment Costs
18
CostOfRoadsRailroadsAndBridgesHydroelectricProduction
Roads, Railroads, and Bridges
19
AssetRetirementCostsHydroelectricProduction
Asset Retirement Costs
20
CostOfPlant
Total cost (total 13 thru 20)
21
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 20 / 5)
22
ProductionExpensesAbstract
Production Expenses
23
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
24
WaterForPower
Water for Power
25
HydraulicExpenses
Hydraulic Expenses
26
ElectricExpensesHydraulicPowerGeneration
Electric Expenses
27
MiscellaneousHydraulicPowerGenerationExpenses
Misc Hydraulic Power Generation Expenses
28
RentsHydraulicPowerGeneration
Rents
29
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
Maintenance Supervision and Engineering
30
MaintenanceOfStructuresHydraulicPowerGeneration
Maintenance of Structures
31
MaintenanceOfReservoirsDamsAndWaterways
Maintenance of Reservoirs, Dams, and Waterways
32
MaintenanceOfElectricPlantHydraulicPowerGeneration
Maintenance of Electric Plant
33
MaintenanceOfMiscellaneousHydraulicPlant
Maintenance of Misc Hydraulic Plant
34
PowerProductionExpensesHydraulicPower
Total Production Expenses (total 23 thru 33)
35
ExpensesPerNetKilowattHour
Expenses per net KWh


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 the 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.
Plant Name:
FERC Licensed Project No.
Plant Name:
FERC Licensed Project No.
Plant Name:
FERC Licensed Project No.
Plant Name:
1
PlantConstructionType
Type of Plant Construction (Conventional or Outdoor)
2
YearPlantOriginallyConstructed
Year Originally Constructed
3
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
4
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
5
NetPeakDemandOnPlant
Net Peak Demaind on Plant-Megawatts (60 minutes)
6
PlantHoursConnectedToLoad
Plant Hours Connect to Load While Generating
7
NetContinuousPlantCapability
Net Plant Capability (in megawatts)
8
PlantAverageNumberOfEmployees
Average Number of Employees
9
NetGenerationExcludingPlantUse
Generation, Exclusive of Plant Use - Kwh
10
EnergyUsedForPumping
Energy Used for Pumping
11
NetOutputForLoad
Net Output for Load (line 9 - line 10) - Kwh
12
CostOfPlantAbstract
Cost of Plant
13
CostOfLandAndLandRightsPumpedStoragePlant
Land and Land Rights
14
CostOfStructuresAndImprovementsPumpedStoragePlant
Structures and Improvements
15
CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Reservoirs, Dams, and Waterways
16
CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant
Water Wheels, Turbines, and Generators
17
CostOfAccessoryElectricEquipmentPumpedStoragePlant
Accessory Electric Equipment
18
CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant
Miscellaneous Powerplant Equipment
19
CostOfRoadsRailroadsAndBridgesPumpedStoragePlant
Roads, Railroads, and Bridges
20
AssetRetirementCostsPumpedStoragePlant
Asset Retirement Costs
21
CostOfPlant
Total cost (total 13 thru 20)
22
CostPerKilowattOfInstalledCapacity
Cost per KW of installed cap (line 21 / 4)
23
ProductionExpensesAbstract
Production Expenses
24
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
25
WaterForPower
Water for Power
26
PumpedStorageExpenses
Pumped Storage Expenses
27
ElectricExpensesPumpedStoragePlant
Electric Expenses
28
MiscellaneousPumpedStoragePowerGenerationExpenses
Misc Pumped Storage Power generation Expenses
29
RentsPumpedStoragePlant
Rents
30
MaintenanceSupervisionAndEngineeringPumpedStoragePlant
Maintenance Supervision and Engineering
31
MaintenanceOfStructuresPumpedStoragePlant
Maintenance of Structures
32
MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Maintenance of Reservoirs, Dams, and Waterways
33
MaintenanceOfElectricPlantPumpedStoragePlant
Maintenance of Electric Plant
34
MaintenanceOfMiscellaneousPumpedStoragePlant
Maintenance of Misc Pumped Storage Plant
35
PowerProductionExpenseBeforePumpingExpenses
Production Exp Before Pumping Exp (24 thru 34)
36
PumpingExpenses
Pumping Expenses
37
PowerProductionExpensesPumpedStoragePlant
Total Production Exp (total 35 and 36)
38
ExpensesPerNetKilowattHour
Expenses per KWh (line 37 / 9)
39
ExpensesPerNetKilowattHourGenerationAndPumping
Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 403. 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)
Net Peak Demand MW (60 min)
(d)
NetGenerationExcludingPlantUse
Net Generation Excluding Plant Use
(e)
Cost of Plant
(f)
PlantCostPerMw
Plant Cost (Incl Asset Retire. Costs) Per MW
(g)
OperatingExpensesExcludingFuel
Operation Exc'l. Fuel
(h)
Fuel Production Expenses
(i)
MaintenanceProductionExpenses
Maintenance Production Expenses
(j)
FuelKind
Kind of Fuel
(k)
FuelCostPerMmbtus
Fuel Costs (in cents (per Million Btu)
(l)
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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 Transmission
(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
35 TOTAL


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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.
  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. Report data by individual lines for all voltages if so required by a State commission.
  4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.
  5. 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.
  6. 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.
  7. 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).
  8. 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.
  9. 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.
  10. 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
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
AssetRetirementCostsTransmissionLines
Asset Retire. Costs
CostOfTransmissionLinesAdded
Total
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
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
TOTAL


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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.
VOLTAGE (In MVa)
Line No.
SubstationNameAndLocation
Name and Location of Substation
(a)
SubstationCharacterDescription
Character of Substation
(b)
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
Conversion Apparatus and Special Equipment, Type of Equipment
(i)
NumberOfConversionApparatusAndSpecialEquipmentUnits
Conversion Apparatus and Special Equipment, Number of Units
(j)
CapacityOfConversionApparatusAndSpecialEquipment
Conversion Apparatus and Special Equipment, Total Capacity (In MVa)
(k)
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


Name of Respondent:

California Independent System Operator Corporation
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/18/2019
Year/Period of Report

End of:
2018
/
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
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
Non-power Goods or Services Provided for Affiliated
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42

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