221191222192331912341924719312481912591912510192261119412620527120612732072852081286209297201012982011309201213010201331112014131211532221161323211733421181335211934621113472123582131359215361121613612271372229383221013842211395221139622101408222140922102110223211221033234412310452235642310515236101623106272371028231073923810310231084112391382383384385386387388389381138103839239339439539639739113910394014034044054074084094011401040411412413414415416417418419411141104114224244254264274284294213332331033332034333035334033450313460323443341044342045343043540413550423560433554351055352051305140510150520160530164011065012066013067014068015069016062710210720220730230740240750250760260770288021089022083308103408203508303608403950310960320970330980340990350946091041021923931933941943951953961963971973981983991993920401201402202403203404204405205406206407207408208409202213121422153216421752186219721128212192122222312224222253222642227522286222972230822319223223331233422335323364233752338623777237882369233224311243725508638

Other (Specify):

CIAC Deferred Taxes

$ 21,993,027

 

Investment Impairment

13,983

 

Other BTL DIT

3,501,628

Total Other

 

 

$ 25,508,638

26462305

Other (Specify):

CIAC Deferred Taxes

$ 22,867,126

 

Investment Impairment

13,657

 

Other BTL DIT

3,581,522

Total Other

 

 

$ 26,462,305

10424109251241010210522411036324111031064241114752412104107624112587241361088241131069924141071091024114810112415108110251159111251610911122511610123251711011242518111913525111146252012172521112210252213311252311342624145126251146226261573262716842628116952629171726301172826311183926321961026331197112634208273512091273621102273722113273812212427392313627401231472741241582711241692742517102751251811276261928712620128827212281012822328112923528121292462813303673103811601659193930981723Purchases/Transfers:139131647500235160003087430-2104500923030613744193000496032501371701006914290400025610Purchases/Transfers:829300023000784622375011038105341457874987734949500500002602335868789418768610100352000105647126299214492800014614020410423041142404435041436042437043438044439046435743105843205943305104340511435054460514470534480544490554466441067442068443069444064550614560624570634580654590664578451079452074630714640724650734660754670764680747907147824710834720854730894740848508248608348708548808948908499249109949110210310410510610111112113114115116111211221231241251261213113213313413513613141142143144145146141511521531541551561516116216316416516616171172243532413424552433624147241582469242251112510822517325642555253532625Not PreparedOriginal value: 2725682524925332612612610522610632627426552666261117264826229261272713127102272532710342740527562714727318271292772811284228114328384281185283628672823828112928C0011431222928129411418192021242526272831323334353738394041424344464748495051525671920313253646517113579111315130311313213233133343536383940123456789101112131415161718192013579111315171921232527121257282172682831727928417281128517292961730129183132911832429218335293183462941835729518368296183792919381029119393021940230319413304194243051943530619456302012830120112930220212113032031231420412131520512231620612331217124311218125312219126313211012731421111283152113931621113113122213103112241313222251323232261343242271353252281363223913732123101311322231113103232314334231141335232142332431433312441443322451453332461473342420169502186072509505890211933781000032216151000724757919684000113959613167410512933321114000413337554304582373393700510200011523715366720160100212793421022027800020273281103318320356692000442128563588910526900020574882106272532957206109475781089109111111211213114151151617117118191202093094095096097098099091011021031041051061071081091011111211311411511611711811911121122123124125126127128129121311321331341351361371381391314114328191521421138251183493972731623329936243101261671726361271122131251131021229101093711032293294295296297298299293013023033043053063073083093031131231331431531631731831931321322323324325326327328329323313323333343353363373383381793313416201341719211234567O89101112123FalseOriginal value: N461214151617181110121023103410451056106710781089109101101111183393311331033341342343344345346347348349341134103435135235335435635735835935113510353613623633643653663673683693611361036371372373375376378379371137103738101210220231032034104204510520561062067107810820891092091011021011111211121122121321314114151151611617117118191192012021121714215248141212591422125111412222515233251151244252152552531512526415261265151262266152732671512842681529526915129271015301271115130227163232711613242721633527316Other (CIAC Deferred Taxes)13328416351285161352286163632871613642881613752891638291016391291116139229171403291174142921742529317142304171431305174423061714433071745430817153091710131101720113111173012311840133111850143121860153131823241810213251820223261830233210184024321118502532196023321431441451461471481491415115215315415515615715815915Original value: NA16Original value: NA116Original value: NA216Original value: NA316Original value: NA416Original value: NA516Original value: NA616Original value: NA716Original value: NA816Original value: NA916Original value: NA17Original value: NA117Original value: NA217Original value: NA317Original value: NA417Original value: NA517Original value: NA617Original value: NA717Original value: NA817Original value: NA917Original value: NA18Original value: NA118Original value: NA218Original value: NA318Original value: NA418Original value: NA518618718818918191192343344345346347348349343513523533543553563573583593536136236336436536636736836936371372373374375376377378379373813823833843853863873883893839139251534253043941312318TOTAL10715124228146304010411102010121241121211348311321412114487151111566698916317721181191202272182226237324716251813264272288629763052931126432TrueOriginal value: 1Duplicate fact discrepancy. Schedule: 106 - Schedule - Information on Formula Rates, Row: 1, Column: c, Value: 0511017118129121250134151427416TrueOriginal value: 17117281841202942112277224231247425126560294553033113263322341535132111
C001143 9-6 2018-12-31 C001143 3-14 2018-01-01 2018-12-31 C001143 0-41 2018-01-01 2018-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 3-13 2018-01-01 2018-12-31 C001143 0-9 2018-01-01 2018-12-31 C001143 6-36 2018-01-01 2018-12-31 C001143 5-21 2018-01-01 2018-12-31 C001143 ferc:OtherUtilityOrNonutilityMember 0-15 2018-01-01 2018-12-31 C001143 ferc:OtherUtilityOrNonutilityMember 0-11 2017-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 11-20 2018-01-01 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 0-18 2018-01-01 2018-12-31 C001143 7-42 2018-01-01 2018-12-31 C001143 0-12 2018-12-31 C001143 0-31 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 5-28 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 3-4 2018-01-01 2018-12-31 C001143 1-29 2018-01-01 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 3-28 2018-01-01 2018-12-31 C001143 0-9 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 5-9 2018-01-01 2018-12-31 C001143 4-14 2018-12-31 C001143 9-15 2018-01-01 2018-12-31 C001143 8-23 2018-01-01 2018-12-31 C001143 0-35 2018-01-01 2018-12-31 C001143 0-4 2018-01-01 2018-12-31 C001143 ferc:Quarter3Member 0 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 2-14 2018-12-31 C001143 1-8 2018-12-31 C001143 0-36 2018-01-01 2018-12-31 C001143 0-2 2018-01-01 2018-12-31 C001143 0-8 2018-01-01 2018-06-30 C001143 3-9 2018-01-01 2018-12-31 C001143 7-1 2018-01-01 2018-12-31 C001143 4-7 2018-01-01 2018-12-31 C001143 0-25 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-39 2018-01-01 2018-12-31 C001143 1-25 2018-01-01 2018-12-31 C001143 5-16 2018-01-01 2018-12-31 C001143 2-4 2018-01-01 2018-12-31 C001143 6-11 2018-01-01 2018-12-31 C001143 0-9 2018-01-01 2018-12-31 C001143 1-37 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 0-33 2018-01-01 2018-12-31 C001143 0-26 2018-01-01 2018-12-31 C001143 0-26 2018-01-01 2018-12-31 C001143 1-3 2018-01-01 2018-12-31 C001143 0-44 2018-01-01 2018-12-31 C001143 5-40 2018-12-31 C001143 Sycamore-1 2018-01-01 2018-12-31 C001143 Coal-1 Electrifarm-1 2018-01-01 2018-12-31 C001143 6-10 2018-01-01 2018-12-31 C001143 Greater Des Moines-2 2018-01-01 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 1-9 2018-01-01 2018-12-31 C001143 0-16 2018-01-01 2018-12-31 C001143 8-42 2018-01-01 2018-12-31 C001143 5-25 2018-01-01 2018-12-31 C001143 8-38 2018-01-01 2018-12-31 C001143 0-34 2018-01-01 2018-12-31 C001143 1-8 2018-01-01 2018-12-31 C001143 9-15 2018-01-01 2018-12-31 C001143 1-12 2018-01-01 2018-12-31 C001143 1-23 2018-01-01 2018-12-31 C001143 0-11 2018-12-31 C001143 ferc:OperatingReserveSpinningMember 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 3-7 2018-01-01 2018-12-31 C001143 9-36 2018-12-31 C001143 ferc:ElectricUtilityMember 0-21 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-18 2018-12-31 C001143 0-27 2018-01-01 2018-12-31 C001143 7-4 2018-01-01 2018-12-31 C001143 9-29 2018-12-31 C001143 0-18 2018-01-01 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 2-2 2018-12-31 C001143 5-24 2018-12-31 C001143 7-25 2018-01-01 2018-12-31 C001143 0-16 2017-12-31 C001143 6-17 2018-01-01 2018-12-31 C001143 7-23 2018-01-01 2018-12-31 C001143 1-5 2018-01-01 2018-12-31 C001143 0-42 2018-01-01 2018-12-31 C001143 0-25 2018-12-31 C001143 0-8 2018-01-01 2018-12-31 C001143 0-22 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-8 2018-01-01 2018-12-31 C001143 6-17 2018-01-01 2018-12-31 C001143 2-22 2018-12-31 C001143 Oil-0 Neal #3-0 2018-01-01 2018-12-31 C001143 0-39 2018-01-01 2018-12-31 C001143 ferc:SulfurDioxideMember ferc:NextTwelveMonthsMember 2018-01-01 2018-12-31 C001143 9-26 2018-12-31 C001143 0-2 2018-01-01 2018-03-31 C001143 0-9 2018-01-01 2018-12-31 C001143 1-43 2018-01-01 2018-12-31 C001143 2-10 2018-01-01 2018-12-31 C001143 1-34 2018-01-01 2018-12-31 C001143 0-8 2018-01-01 2018-12-31 C001143 1-11 2017-12-31 C001143 ferc:SulfurDioxideMember ferc:NextTwelveMonthsMember 2017-12-31 C001143 0-17 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 0-2 2018-01-01 2018-06-30 C001143 0-34 2018-12-31 C001143 0-22 2018-01-01 2018-12-31 C001143 0-3 2018-01-01 2018-12-31 C001143 8-38 2018-01-01 2018-12-31 C001143 5-13 2018-01-01 2018-12-31 C001143 3-9 2018-12-31 C001143 ferc:ElectricUtilityMember 0-10 2018-01-01 2018-12-31 C001143 3-29 2018-01-01 2018-12-31 C001143 8-20 2018-12-31 C001143 1-5 2018-01-01 2018-12-31 C001143 ferc:OtherUtilityOrNonutilityMember 0-15 2018-12-31 C001143 6-16 2018-12-31 C001143 0-24 2018-01-01 2018-12-31 C001143 2-11 2018-01-01 2018-12-31 C001143 0-3 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 8-11 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-29 2018-01-01 2018-12-31 C001143 0-23 2018-01-01 2018-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 0-51 2018-01-01 2018-12-31 C001143 5-15 2018-01-01 2018-12-31 C001143 4-24 2018-01-01 2018-12-31 C001143 1-24 2018-01-01 2018-12-31 C001143 1-15 2018-01-01 2018-12-31 C001143 7-1 2018-12-31 C001143 0-3 2018-01-01 2018-12-31 C001143 ferc:OtherUtilityMember 0-17 2018-12-31 C001143 5-26 2018-12-31 C001143 0-2 2018-12-31 C001143 ferc:ElectricUtilityMember 0-27 2018-01-01 2018-12-31 C001143 4-16 2018-01-01 2018-12-31 C001143 1-42 2018-01-01 2018-12-31 C001143 0-65 2017-01-01 2017-12-31 C001143 1-33 2018-12-31 C001143 ferc:GenerationStudiesMember 0-34 2018-01-01 2018-12-31 C001143 3-7 2018-01-01 2018-12-31 C001143 0-7 2017-12-31 C001143 ferc:ElectricUtilityMember 0-24 2018-12-31 C001143 0-14 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 5-38 2018-01-01 2018-12-31 C001143 0-23 2018-01-01 2018-12-31 C001143 8-17 2018-01-01 2018-12-31 C001143 2-21 2018-01-01 2018-12-31 C001143 7-13 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 0-11 2017-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 5-19 2018-01-01 2018-12-31 C001143 1-4 2018-12-31 C001143 1-44 2018-01-01 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 5-30 2018-01-01 2018-12-31 C001143 0-6 2018-12-31 C001143 9-39 2018-12-31 C001143 1-25 2018-01-01 2018-12-31 C001143 0-15 2017-12-31 C001143 ferc:GenerationStudiesMember 0-30 2018-01-01 2018-12-31 C001143 0-20 2018-01-01 2018-12-31 C001143 0-17 2018-01-01 2018-12-31 C001143 8-40 2018-01-01 2018-12-31 C001143 0-12 2018-01-01 2018-12-31 C001143 10-17 2018-01-01 2018-12-31 C001143 0-25 2018-01-01 2018-12-31 C001143 1-10 2018-01-01 2018-12-31 C001143 2-6 2018-01-01 2018-12-31 C001143 Gas-1 Sycamore-1 2018-01-01 2018-12-31 C001143 1-5 2018-01-01 2018-12-31 C001143 0-10 2017-12-31 C001143 Oil-1 Pleasant Hill-1 2018-01-01 2018-12-31 C001143 9-13 2018-12-31 C001143 0-34 2018-01-01 2018-12-31 C001143 2-12 2018-01-01 2018-12-31 C001143 8-16 2018-01-01 2018-12-31 C001143 8-18 2018-01-01 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 4-1 2018-01-01 2018-12-31 C001143 4-4 2018-12-31 C001143 0-27 2018-01-01 2018-12-31 C001143 7-33 2018-01-01 2018-12-31 C001143 2-5 2018-01-01 2018-12-31 C001143 0-39 2018-01-01 2018-12-31 C001143 2-24 2018-01-01 2018-12-31 C001143 4-23 2018-01-01 2018-12-31 C001143 0-2 2018-12-31 C001143 ferc:DirectPayrollDistributionMember 0-78 2018-01-01 2018-12-31 C001143 0-29 2018-01-01 2018-12-31 C001143 3-10 2018-12-31 C001143 5-28 2018-12-31 C001143 8-30 2018-01-01 2018-12-31 C001143 8-35 2018-01-01 2018-12-31 C001143 1-14 2018-01-01 2018-12-31 C001143 ferc:IntangiblePlantMember ferc:ElectricUtilityMember 2018-01-01 2018-12-31 C001143 7-35 2018-01-01 2018-12-31 C001143 ferc:LandAndRightsMember 0-15 2018-12-31 C001143 3-6 2018-01-01 2018-12-31 C001143 1-42 2018-01-01 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 7-17 2018-01-01 2018-12-31 C001143 3-32 2018-01-01 2018-12-31 C001143 0-41 2018-01-01 2018-12-31 C001143 Oil-0 Neal #4-0 2018-01-01 2018-12-31 C001143 3-11 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-4 2018-01-01 2018-12-31 C001143 Gas-2 Moline-2 2018-01-01 2018-12-31 C001143 0-8 2018-01-01 2018-09-30 C001143 9-33 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-06-30 C001143 0-9 2017-12-31 C001143 0-19 2017-12-31 C001143 3-2 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 Gas-1 Riverside-1 2018-01-01 2018-12-31 C001143 2-4 2018-01-01 2018-12-31 C001143 6-42 2018-01-01 2018-12-31 C001143 4-19 2018-01-01 2018-12-31 C001143 7-15 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 0-20 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 1-12 2018-01-01 2018-12-31 C001143 1-33 2018-01-01 2018-12-31 C001143 9-27 2018-12-31 C001143 4-16 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-41 2018-12-31 C001143 1-30 2018-01-01 2018-12-31 C001143 ferc:NitrogenOxideMember ferc:NextTwelveMonthsMember 2018-01-01 2018-12-31 C001143 11-16 2018-01-01 2018-12-31 C001143 0-3 2017-12-31 C001143 0-45 2018-01-01 2018-12-31 C001143 1-16 2018-01-01 2018-12-31 C001143 11-23 2018-01-01 2018-12-31 C001143 1-10 2018-01-01 2018-12-31 C001143 1-28 2018-01-01 2018-12-31 C001143 ferc:SulfurDioxideMember ferc:CurrentYearMember 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 1-12 2018-12-31 C001143 Oil-2 Greater Des Moines-2 2018-01-01 2018-12-31 C001143 5-47 2018-01-01 2018-12-31 C001143 6-22 2018-12-31 C001143 7-5 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 8-4 2018-01-01 2018-12-31 C001143 0-36 2018-01-01 2018-12-31 C001143 5-21 2018-12-31 C001143 0-34 2018-01-01 2018-12-31 C001143 0-20 2018-01-01 2018-12-31 C001143 ferc:HydraulicProductionPlantConventionalMember ferc:ElectricUtilityMember 2018-01-01 2018-12-31 C001143 5-4 2018-01-01 2018-12-31 C001143 0-9 2018-01-01 2018-12-31 C001143 2-15 2018-01-01 2018-12-31 C001143 5-36 2018-01-01 2018-12-31 C001143 7-26 2018-01-01 2018-12-31 C001143 1-24 2018-01-01 2018-12-31 C001143 3-24 2018-01-01 2018-12-31 C001143 10-41 2018-01-01 2018-12-31 C001143 ferc:GenerationStudiesMember 1-23 2018-01-01 2018-12-31 C001143 0-7 2018-12-31 C001143 3-27 2018-01-01 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-5 2018-12-31 C001143 0-16 2018-01-01 2018-12-31 C001143 0-17 2017-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 5-41 2018-01-01 2018-12-31 C001143 0-9 2018-01-01 2018-12-31 C001143 2-50 2018-01-01 2018-12-31 C001143 0-38 2018-01-01 2018-12-31 C001143 9-14 2018-01-01 2018-12-31 C001143 7-27 2018-12-31 C001143 0-17 2017-12-31 C001143 2-6 2018-01-01 2018-12-31 C001143 7-14 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 0-52 2018-01-01 2018-12-31 C001143 0-27 2018-01-01 2018-12-31 C001143 2-25 2018-01-01 2018-12-31 C001143 7-12 2018-01-01 2018-12-31 C001143 2018-01-01 2018-06-30 C001143 0-40 2017-12-31 C001143 6-35 2018-01-01 2018-12-31 C001143 ferc:DecemberMember 0 2018-01-01 2018-12-31 C001143 1-3 2018-01-01 2018-12-31 C001143 2-27 2018-01-01 2018-12-31 C001143 1-17 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-13 2018-01-01 2018-12-31 C001143 0-6 2017-12-31 C001143 1-36 2018-01-01 2018-12-31 C001143 1-32 2018-12-31 C001143 0-7 2017-12-31 C001143 7-36 2018-01-01 2018-12-31 C001143 Quad-Cities-2 2018-01-01 2018-12-31 C001143 0-8 2018-01-01 2018-12-31 C001143 0-24 2018-12-31 C001143 4-44 2018-01-01 2018-12-31 C001143 6-6 2018-01-01 2018-12-31 C001143 6-1 2018-01-01 2018-12-31 C001143 6-18 2018-01-01 2018-12-31 C001143 0-38 2018-01-01 2018-12-31 C001143 0-3 2017-12-31 C001143 4-6 2018-01-01 2018-12-31 C001143 2-1 2018-01-01 2018-12-31 C001143 0-49 2018-01-01 2018-12-31 C001143 1-8 2018-01-01 2018-12-31 C001143 0-30 2018-01-01 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-4 2018-01-01 2018-12-31 C001143 3-18 2018-01-01 2018-12-31 C001143 5-17 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 9-12 2018-01-01 2018-12-31 C001143 1-32 2018-12-31 C001143 2-10 2018-12-31 C001143 6-39 2018-01-01 2018-12-31 C001143 1-40 2018-01-01 2018-12-31 C001143 Oil-1 Sycamore-1 2018-01-01 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 11-15 2018-01-01 2018-12-31 C001143 Gas-0 Neal #3-0 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-34 2018-12-31 C001143 Oil-1 River Hills-1 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 2-28 2018-01-01 2018-12-31 C001143 0-7 2018-12-31 C001143 1-38 2018-12-31 C001143 8-35 2018-01-01 2018-12-31 C001143 0-33 2018-01-01 2018-12-31 C001143 1-1 2018-01-01 2018-12-31 C001143 7-6 2018-01-01 2018-12-31 C001143 ferc:OperatingUtilityMember 2018-12-31 C001143 ferc:ElectricPlantInServiceMember ferc:ElectricUtilityMember 2018-01-01 2018-12-31 C001143 0-44 2018-01-01 2018-12-31 C001143 10-35 2018-01-01 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 1-17 2018-01-01 2018-12-31 C001143 0-19 2018-12-31 C001143 9-3 2018-01-01 2018-12-31 C001143 0-8 2018-01-01 2018-12-31 C001143 4-28 2018-01-01 2018-12-31 C001143 2-11 2018-12-31 C001143 0-27 2018-01-01 2018-12-31 C001143 1-27 2018-01-01 2018-12-31 C001143 0-3 2018-12-31 C001143 7-20 2018-12-31 C001143 ferc:ElectricUtilityMember 1-14 2018-12-31 C001143 0-19 2017-12-31 C001143 0-37 2018-01-01 2018-12-31 C001143 7-18 2018-01-01 2018-12-31 C001143 6-4 2018-01-01 2018-12-31 C001143 0-11 2018-12-31 C001143 0-3 2017-12-31 C001143 ferc:OtherUtilityMember 2017-12-31 C001143 1-8 2018-01-01 2018-12-31 C001143 6-12 2018-01-01 2018-12-31 C001143 0-3 2018-12-31 C001143 1-19 2018-12-31 C001143 1-6 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-3 2018-01-01 2018-12-31 C001143 1-39 2018-01-01 2018-12-31 C001143 6-36 2018-01-01 2018-12-31 C001143 0-28 2018-01-01 2018-12-31 C001143 6-21 2018-12-31 C001143 ferc:SulfurDioxideMember 1 2018-01-01 2018-12-31 C001143 1-13 2018-01-01 2018-12-31 C001143 0-40 2018-01-01 2018-12-31 C001143 5-31 2018-01-01 2018-12-31 C001143 5-16 2018-01-01 2018-12-31 C001143 0-32 2018-01-01 2018-12-31 C001143 0-25 2018-12-31 C001143 4-18 2018-12-31 C001143 ferc:ThreeYearsMember ferc:NitrogenOxideMember 2018-01-01 2018-12-31 C001143 0-2 2018-12-31 C001143 6 2018-01-01 2018-12-31 C001143 0-13 2018-12-31 C001143 8-19 2018-01-01 2018-12-31 C001143 9-34 2018-12-31 C001143 3-41 2018-01-01 2018-12-31 C001143 8-9 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-6 2018-01-01 2018-12-31 C001143 4-39 2018-01-01 2018-12-31 C001143 2-31 2018-01-01 2018-12-31 C001143 4-36 2018-12-31 C001143 9-38 2018-01-01 2018-12-31 C001143 2-3 2018-12-31 C001143 1-24 2018-01-01 2018-12-31 C001143 0-32 2018-01-01 2018-12-31 C001143 1-32 2018-01-01 2018-12-31 C001143 8-37 2018-01-01 2018-12-31 C001143 1-8 2018-01-01 2018-12-31 C001143 Coal-3 Walter Scott #4-3 2018-01-01 2018-12-31 C001143 1-29 2018-01-01 2018-12-31 C001143 ferc:ThreeYearsMember ferc:NitrogenOxideMember 2018-12-31 C001143 4-27 2018-01-01 2018-12-31 C001143 SchedulePumpedStorageGeneratingPlantStatisticsAbstract 2018-01-01 2018-12-31 C001143 3-16 2018-12-31 C001143 5-8 2018-01-01 2018-12-31 C001143 0-17 2017-12-31 C001143 0-29 2018-12-31 C001143 0-34 2018-01-01 2018-12-31 C001143 0-4 2017-12-31 C001143 3-37 2018-12-31 C001143 6-6 2018-12-31 C001143 1-19 2018-01-01 2018-12-31 C001143 0-40 2018-01-01 2018-12-31 C001143 2-2 2018-01-01 2018-12-31 C001143 8-45 2018-01-01 2018-12-31 C001143 1-16 2018-01-01 2018-12-31 C001143 0-12 2018-01-01 2018-12-31 C001143 0-34 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 ferc:NitrogenOxideMember ferc:CurrentYearMember 2017-12-31 C001143 3-33 2018-01-01 2018-12-31 C001143 8-33 2018-12-31 C001143 0-28 2018-12-31 C001143 5-6 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 1-18 2018-01-01 2018-12-31 C001143 4-25 2018-12-31 C001143 2-30 2018-01-01 2018-12-31 C001143 1-23 2017-12-31 C001143 8-9 2018-12-31 C001143 5-18 2018-12-31 C001143 7-43 2018-01-01 2018-12-31 C001143 1-25 2018-12-31 C001143 2-14 2018-01-01 2018-12-31 C001143 4-21 2018-12-31 C001143 4-30 2018-12-31 C001143 0-20 2018-12-31 C001143 0-3 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-14 2018-12-31 C001143 3-22 2018-01-01 2018-12-31 C001143 1-2 2017-12-31 C001143 0-18 2017-12-31 C001143 3-12 2018-01-01 2018-12-31 C001143 7-34 2018-01-01 2018-12-31 C001143 5-48 2018-01-01 2018-12-31 C001143 4-21 2018-01-01 2018-12-31 C001143 7-29 2018-01-01 2018-12-31 C001143 3-30 2018-12-31 C001143 9-31 2018-01-01 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-30 2018-12-31 C001143 9-25 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-2 2018-01-01 2018-12-31 C001143 4-19 2018-12-31 C001143 1-9 2017-12-31 C001143 1-9 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 1-4 2018-01-01 2018-12-31 C001143 9-43 2018-01-01 2018-12-31 C001143 3-35 2018-12-31 C001143 9-42 2018-01-01 2018-12-31 C001143 0-34 2018-01-01 2018-12-31 C001143 0-8 2018-01-01 2018-12-31 C001143 4-16 2018-12-31 C001143 0-33 2018-12-31 C001143 ferc:SulfurDioxideMember ferc:NextTwelveMonthsMember 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 0-30 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 1-11 2018-01-01 2018-12-31 C001143 0-38 2018-01-01 2018-12-31 C001143 1-30 2018-01-01 2018-12-31 C001143 1-35 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 0-6 2017-12-31 C001143 0-5 2017-12-31 C001143 8-21 2018-12-31 C001143 0-9 2018-01-01 2018-03-31 C001143 0-41 2018-01-01 2018-12-31 C001143 9-1 2018-12-31 C001143 0-35 2018-01-01 2018-12-31 C001143 2-9 2018-01-01 2018-12-31 C001143 0-22 2018-01-01 2018-12-31 C001143 8-13 2018-12-31 C001143 0-8 2017-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 6-12 2018-12-31 C001143 2-3 2018-01-01 2018-12-31 C001143 3-24 2018-01-01 2018-12-31 C001143 1-10 2018-01-01 2018-12-31 C001143 5-2 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-2 2018-12-31 C001143 5-33 2018-12-31 C001143 0-29 2018-01-01 2018-12-31 C001143 5-30 2018-01-01 2018-12-31 C001143 2-18 2018-01-01 2018-12-31 C001143 0-8 2018-01-01 2018-12-31 C001143 6-28 2018-12-31 C001143 0-17 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 0-20 2018-01-01 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 ferc:TwoYearsMember ferc:NitrogenOxideMember 2018-12-31 C001143 4-15 2018-01-01 2018-12-31 C001143 9-3 2018-12-31 C001143 2-8 2018-01-01 2018-12-31 C001143 3-13 2018-12-31 C001143 ferc:ElectricUtilityMember 0-19 2018-12-31 C001143 0-9 2018-01-01 2018-12-31 C001143 1-2 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-5 2018-12-31 C001143 1-18 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-2 2017-12-31 C001143 0-23 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 ferc:SeptemberMember 0 2018-01-01 2018-12-31 C001143 ferc:ElectricPlantInServiceMember ferc:ElectricUtilityMember 2018-12-31 C001143 ferc:ElectricUtilityMember 0-1 2018-01-01 2018-12-31 C001143 0-33 2018-01-01 2018-12-31 C001143 0-5 2018-12-31 C001143 ferc:ElectricUtilityMember 0-4 2017-12-31 C001143 ferc:LandAndRightsMember 0-7 2018-12-31 C001143 7-16 2018-01-01 2018-12-31 C001143 0-42 2018-01-01 2018-12-31 C001143 6-7 2018-12-31 C001143 0-2 2018-01-01 2018-12-31 C001143 ferc:GasUtilityMember 0-12 2018-01-01 2018-12-31 C001143 0-19 2018-12-31 C001143 0-1 2018-12-31 C001143 8-40 2018-12-31 C001143 1-31 2018-01-01 2018-12-31 C001143 11-39 2018-01-01 2018-12-31 C001143 0-78 2018-01-01 2018-12-31 C001143 0 2018-01-01 2018-12-31 C001143 7-31 2018-12-31 C001143 6-6 2018-01-01 2018-12-31 C001143 0-17 2018-01-01 2018-12-31 C001143 ferc:OtherUtilityOrNonutilityMember 0-11 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-36 2018-01-01 2018-12-31 C001143 0-16 2017-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 0-1 2017-12-31 C001143 1-4 2018-01-01 2018-12-31 C001143 8-17 2018-01-01 2018-12-31 C001143 1-5 2018-01-01 2018-12-31 C001143 0-30 2018-01-01 2018-12-31 C001143 1-25 2018-01-01 2018-12-31 C001143 0-37 2018-01-01 2018-12-31 C001143 1-26 2018-01-01 2018-12-31 C001143 0-9 2018-01-01 2018-12-31 C001143 0-12 2018-01-01 2018-12-31 C001143 0-2 2018-01-01 2018-12-31 C001143 0-2 2018-01-01 2018-12-31 C001143 0-3 2018-01-01 2018-12-31 C001143 1-17 2017-12-31 C001143 0-37 2018-01-01 2018-12-31 C001143 0-9 2018-12-31 C001143 4-31 2018-01-01 2018-12-31 C001143 1-15 2018-01-01 2018-12-31 C001143 0-35 2018-01-01 2018-12-31 C001143 3-29 2018-01-01 2018-12-31 C001143 2018-01-01 2018-09-30 C001143 0-65 2018-01-01 2018-12-31 C001143 7-35 2018-01-01 2018-12-31 C001143 0-3 2018-12-31 C001143 0-5 2018-12-31 C001143 0-17 2018-12-31 C001143 0-23 2018-12-31 C001143 8-34 2018-01-01 2018-12-31 C001143 0-3 2018-12-31 C001143 8-7 2018-12-31 C001143 9-21 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-2 2018-12-31 C001143 8-3 2018-01-01 2018-12-31 C001143 7-40 2018-12-31 C001143 7-38 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 6-18 2018-12-31 C001143 4-13 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 1-29 2018-01-01 2018-12-31 C001143 3-32 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 5-20 2018-01-01 2018-12-31 C001143 1-6 2018-01-01 2018-12-31 C001143 2-43 2018-01-01 2018-12-31 C001143 1-17 2018-12-31 C001143 1-19 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 0-17 2018-12-31 C001143 2-28 2018-12-31 C001143 0-12 2018-12-31 C001143 5-31 2018-01-01 2018-12-31 C001143 5-5 2018-01-01 2018-12-31 C001143 0-25 2018-12-31 C001143 7-14 2018-01-01 2018-12-31 C001143 1-28 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 0-8 2018-01-01 2018-12-31 C001143 6-14 2018-12-31 C001143 3-6 2018-01-01 2018-12-31 C001143 1-3 2018-01-01 2018-12-31 C001143 0-4 2018-01-01 2018-12-31 C001143 2-3 2018-01-01 2018-12-31 C001143 ferc:SulfurDioxideMember ferc:AfterThreeYearsMember 2018-01-01 2018-12-31 C001143 7-17 2018-01-01 2018-12-31 C001143 1-35 2018-01-01 2018-12-31 C001143 9-18 2018-12-31 C001143 1-13 2018-01-01 2018-12-31 C001143 0-30 2018-01-01 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 6-22 2018-01-01 2018-12-31 C001143 1-20 2018-01-01 2018-12-31 C001143 1-15 2018-01-01 2018-12-31 C001143 ferc:NitrogenOxideMember ferc:AfterThreeYearsMember 2018-01-01 2018-12-31 C001143 Coal-2 Merl Parr-2 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-17 2018-01-01 2018-12-31 C001143 4-1 2018-12-31 C001143 3-17 2018-01-01 2018-12-31 C001143 0-20 2018-01-01 2018-12-31 C001143 8-31 2018-01-01 2018-12-31 C001143 8-38 2018-12-31 C001143 3-27 2018-12-31 C001143 0-20 2018-01-01 2018-12-31 C001143 Louisa-0 2018-01-01 2018-12-31 C001143 2-8 2018-01-01 2018-12-31 C001143 5-9 2018-12-31 C001143 0-20 2018-01-01 2018-12-31 C001143 0-27 2018-01-01 2018-12-31 C001143 9-2 2018-01-01 2018-12-31 C001143 Walter Scott #4-3 2018-01-01 2018-12-31 C001143 3-20 2018-12-31 C001143 4 2018-01-01 2018-12-31 C001143 9-36 2018-01-01 2018-12-31 C001143 0-38 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-3 2017-12-31 C001143 5-14 2018-01-01 2018-12-31 C001143 1-34 2018-12-31 C001143 7-12 2018-12-31 C001143 6-17 2018-01-01 2018-12-31 C001143 5-29 2018-01-01 2018-12-31 C001143 ferc:LandAndRightsMember 0-15 2018-01-01 2018-12-31 C001143 0-6 2017-12-31 C001143 ferc:GasUtilityMember 0-11 2018-12-31 C001143 3-23 2018-01-01 2018-12-31 C001143 9-32 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 0-2 2018-01-01 2018-12-31 C001143 1-8 2018-01-01 2018-12-31 C001143 0-47 2018-01-01 2018-12-31 C001143 11-32 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-17 2018-01-01 2018-12-31 C001143 0-4 2018-01-01 2018-12-31 C001143 0-26 2018-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 0-16 2018-12-31 C001143 0-18 2018-01-01 2018-12-31 C001143 4-33 2018-01-01 2018-12-31 C001143 4-12 2018-01-01 2018-12-31 C001143 0-25 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-3 2018-12-31 C001143 6-1 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 4-15 2018-01-01 2018-12-31 C001143 8-16 2018-12-31 C001143 3-29 2018-12-31 C001143 3-17 2018-01-01 2018-12-31 C001143 4-29 2018-12-31 C001143 4-35 2018-01-01 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 1-12 2018-01-01 2018-12-31 C001143 0-4 2017-12-31 C001143 11-34 2018-01-01 2018-12-31 C001143 0-7 2017-01-01 2017-12-31 C001143 6-21 2018-01-01 2018-12-31 C001143 4-30 2018-01-01 2018-12-31 C001143 0-1 2018-12-31 C001143 ferc:LandAndRightsMember 0-5 2018-01-01 2018-12-31 C001143 1-12 2018-01-01 2018-12-31 C001143 0-35 2018-01-01 2018-12-31 C001143 0-3 2018-01-01 2018-12-31 C001143 2-14 2018-01-01 2018-12-31 C001143 1-8 2018-12-31 C001143 ferc:ElectricUtilityMember 1-9 2018-12-31 C001143 ferc:GenerationStudiesMember 0-32 2018-01-01 2018-12-31 C001143 1-38 2018-01-01 2018-12-31 C001143 2-22 2018-01-01 2018-12-31 C001143 1-4 2018-12-31 C001143 ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract 2018-01-01 2018-12-31 C001143 0-23 2018-01-01 2018-12-31 C001143 0-40 2018-12-31 C001143 4-11 2018-01-01 2018-12-31 C001143 9-8 2018-01-01 2018-12-31 C001143 0-33 2018-01-01 2018-12-31 C001143 ferc:TwoYearsMember ferc:NitrogenOxideMember 2018-01-01 2018-12-31 C001143 8-24 2018-12-31 C001143 0-22 2018-01-01 2018-12-31 C001143 0-33 2018-01-01 2018-12-31 C001143 1-1 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 ScheduleElectricPropertyLeasedToOthersAbstract 2018-01-01 2018-12-31 C001143 2-41 2018-01-01 2018-12-31 C001143 0-32 2018-01-01 2018-12-31 C001143 0-2 2018-01-01 2018-12-31 C001143 5-11 2018-12-31 C001143 9-48 2018-01-01 2018-12-31 C001143 1-5 2018-12-31 C001143 4-40 2018-12-31 C001143 6-7 2018-01-01 2018-12-31 C001143 3-5 2018-01-01 2018-12-31 C001143 2-19 2018-01-01 2018-12-31 C001143 1-23 2018-12-31 C001143 5-23 2018-01-01 2018-12-31 C001143 ferc:OctoberMember 0 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-3 2018-01-01 2018-12-31 C001143 0-3 2018-01-01 2018-12-31 C001143 0-42 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-29 2018-01-01 2018-12-31 C001143 9-19 2018-12-31 C001143 0-36 2018-01-01 2018-12-31 C001143 6-13 2018-01-01 2018-12-31 C001143 0-28 2018-01-01 2018-12-31 C001143 0-24 2018-01-01 2018-12-31 C001143 9-9 2018-12-31 C001143 9-36 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-7 2018-12-31 C001143 0-16 2018-12-31 C001143 3-10 2018-01-01 2018-12-31 C001143 9-40 2018-01-01 2018-12-31 C001143 10-15 2018-01-01 2018-12-31 C001143 2-37 2018-01-01 2018-12-31 C001143 1-29 2018-12-31 C001143 0-16 2018-01-01 2018-12-31 C001143 3-28 2018-12-31 C001143 0-27 2018-01-01 2018-12-31 C001143 1-2 2018-01-01 2018-12-31 C001143 3-28 2018-01-01 2018-12-31 C001143 0-28 2018-01-01 2018-12-31 C001143 1-32 2018-01-01 2018-12-31 C001143 2-12 2018-01-01 2018-12-31 C001143 4-22 2018-12-31 C001143 0-23 2018-01-01 2018-12-31 C001143 ferc:GeneralPlantMember ferc:ElectricUtilityMember 2018-01-01 2018-12-31 C001143 8-30 2018-12-31 C001143 1-26 2018-01-01 2018-12-31 C001143 ferc:GasUtilityMember 2017-12-31 C001143 1-39 2018-01-01 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 3-35 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 ScheduleTransmissionOfElectricityByIsoOrRtoAbstract 2018-01-01 2018-12-31 C001143 6-15 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-8 2018-12-31 C001143 1-6 2018-01-01 2018-12-31 C001143 1-18 2018-01-01 2018-12-31 C001143 11-27 2018-01-01 2018-12-31 C001143 6-14 2018-01-01 2018-12-31 C001143 0-27 2018-01-01 2018-12-31 C001143 0-40 2018-01-01 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 0-27 2018-12-31 C001143 0-13 2018-12-31 C001143 0-10 2018-12-31 C001143 5-15 2018-01-01 2018-12-31 C001143 2-34 2018-01-01 2018-12-31 C001143 ferc:OperatingReserveSupplementMember 2018-01-01 2018-12-31 C001143 1-32 2017-12-31 C001143 ferc:ElectricUtilityMember 0-23 2018-01-01 2018-12-31 C001143 5 2018-01-01 2018-12-31 C001143 0-40 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-14 2018-01-01 2018-12-31 C001143 6-18 2018-01-01 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 0-38 2018-01-01 2018-12-31 C001143 0-11 2017-12-31 C001143 0-26 2018-01-01 2018-12-31 C001143 2-17 2018-12-31 C001143 Coal-2 Coralville-2 2018-01-01 2018-12-31 C001143 0-17 2018-12-31 C001143 9-44 2018-01-01 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 2-22 2018-01-01 2018-12-31 C001143 0-46 2018-01-01 2018-12-31 C001143 0-16 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-11 2018-01-01 2018-12-31 C001143 ferc:OtherUtilityOrNonutilityMember 0-13 2017-12-31 C001143 ferc:GasUtilityMember 2018-01-01 2018-12-31 C001143 4-27 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-18 2018-12-31 C001143 4 2018-01-01 2018-12-31 C001143 7-15 2018-01-01 2018-12-31 C001143 10-40 2018-01-01 2018-12-31 C001143 9-7 2018-01-01 2018-12-31 C001143 1-12 2018-01-01 2018-12-31 C001143 10-29 2018-01-01 2018-12-31 C001143 ferc:GenerationStudiesMember 0-25 2018-01-01 2018-12-31 C001143 0-6 2018-12-31 C001143 1-17 2018-12-31 C001143 0-12 2018-01-01 2018-12-31 C001143 1-26 2018-01-01 2018-12-31 C001143 1-31 2018-01-01 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 2-32 2018-01-01 2018-12-31 C001143 2-21 2018-01-01 2018-12-31 C001143 6-36 2018-12-31 C001143 0-31 2018-01-01 2018-12-31 C001143 9-26 2018-01-01 2018-12-31 C001143 0-1 2018-12-31 C001143 1-3 2018-01-01 2018-12-31 C001143 1-19 2018-01-01 2018-12-31 C001143 9-27 2018-01-01 2018-12-31 C001143 0-5 2018-12-31 C001143 5-34 2018-01-01 2018-12-31 C001143 1-26 2018-12-31 C001143 0-3 2018-12-31 C001143 0-4 2018-12-31 C001143 ferc:Quarter4Member 0 2018-01-01 2018-12-31 C001143 0-26 2018-01-01 2018-12-31 C001143 0-39 2018-01-01 2018-12-31 C001143 8-4 2018-12-31 C001143 4-37 2018-01-01 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 0-27 2018-01-01 2018-12-31 C001143 Coal-0 Louisa-0 2018-01-01 2018-12-31 C001143 4-9 2018-12-31 C001143 1-37 2018-01-01 2018-12-31 C001143 1-5 2018-01-01 2018-12-31 C001143 5-25 2018-01-01 2018-12-31 C001143 4-34 2018-01-01 2018-12-31 C001143 7-9 2018-01-01 2018-12-31 C001143 ferc:OtherUtilityOrNonutilityMember 0-14 2018-01-01 2018-12-31 C001143 1-1 2018-12-31 C001143 6-30 2018-12-31 C001143 0-13 2018-12-31 C001143 0-41 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 9-17 2018-12-31 C001143 0-8 2018-01-01 2018-12-31 C001143 3-20 2018-01-01 2018-12-31 C001143 5-8 2018-12-31 C001143 3-18 2018-01-01 2018-12-31 C001143 ferc:GenerationStudiesMember 0-22 2018-01-01 2018-12-31 C001143 0-40 2018-01-01 2018-12-31 C001143 5-2 2018-01-01 2018-12-31 C001143 2-10 2018-01-01 2018-12-31 C001143 1-14 2018-12-31 C001143 ferc:OtherUtilityOrNonutilityMember 0-11 2018-12-31 C001143 2-35 2018-01-01 2018-12-31 C001143 1-1 2018-01-01 2018-12-31 C001143 7-7 2018-01-01 2018-12-31 C001143 ferc:ElectricPollutionControlFacilitiesMember 2018-01-01 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 0-35 2018-01-01 2018-12-31 C001143 1-20 2018-01-01 2018-12-31 C001143 5-34 2018-01-01 2018-12-31 C001143 0-35 2018-01-01 2018-12-31 C001143 6-34 2018-12-31 C001143 ferc:SulfurDioxideMember ferc:CurrentYearMember 2018-12-31 C001143 11-18 2018-01-01 2018-12-31 C001143 0-12 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-4 2018-01-01 2018-12-31 C001143 0-4 2017-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 1-30 2018-12-31 C001143 ferc:ElectricUtilityMember 0-6 2017-12-31 C001143 6-27 2018-01-01 2018-12-31 C001143 1-10 2018-12-31 C001143 1-44 2018-01-01 2018-12-31 C001143 4-22 2018-01-01 2018-12-31 C001143 1-46 2018-01-01 2018-12-31 C001143 2-33 2018-12-31 C001143 4-7 2018-12-31 C001143 0-24 2018-01-01 2018-12-31 C001143 2-28 2018-01-01 2018-12-31 C001143 7-44 2018-01-01 2018-12-31 C001143 1-33 2018-01-01 2018-12-31 C001143 2 2018-01-01 2018-12-31 C001143 0-31 2018-01-01 2018-12-31 C001143 8-2 2018-01-01 2018-12-31 C001143 0-8 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-40 2018-12-31 C001143 0-45 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-26 2018-01-01 2018-12-31 C001143 0-16 2018-01-01 2018-12-31 C001143 5-25 2018-01-01 2018-12-31 C001143 6-14 2018-01-01 2018-12-31 C001143 4-8 2018-12-31 C001143 ferc:GasUtilityMember 0-14 2018-01-01 2018-12-31 C001143 0-33 2018-01-01 2018-12-31 C001143 0-9 2018-01-01 2018-12-31 C001143 1-24 2018-01-01 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 0-9 2018-01-01 2018-12-31 C001143 1-22 2018-01-01 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 ScheduleExtraordinaryPropertyLossesAbstract 2018-01-01 2018-12-31 C001143 9-33 2018-01-01 2018-12-31 C001143 3-21 2018-01-01 2018-12-31 C001143 0-28 2018-01-01 2018-12-31 C001143 4-5 2018-01-01 2018-12-31 C001143 4-17 2018-01-01 2018-12-31 C001143 1-15 2018-12-31 C001143 Coal-0 Neal #4-0 2018-01-01 2018-12-31 C001143 0-36 2018-01-01 2018-12-31 C001143 1-3 2018-01-01 2018-12-31 C001143 ferc:OtherUtilityOrNonutilityMember 0-14 2017-12-31 C001143 ferc:ElectricUtilityMember 0-28 2018-12-31 C001143 8-29 2018-01-01 2018-12-31 C001143 3-37 2018-01-01 2018-12-31 C001143 7 2018-01-01 2018-12-31 C001143 3-38 2018-01-01 2018-12-31 C001143 8-24 2018-01-01 2018-12-31 C001143 1-22 2018-01-01 2018-12-31 C001143 2-14 2018-01-01 2018-12-31 C001143 5-21 2018-01-01 2018-12-31 C001143 0-4 2018-12-31 C001143 3-29 2018-01-01 2018-12-31 C001143 0-47 2018-01-01 2018-12-31 C001143 0-12 2018-01-01 2018-12-31 C001143 1-30 2018-01-01 2018-12-31 C001143 ferc:GasUtilityMember 0-10 2018-12-31 C001143 0-9 2018-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 7-13 2018-12-31 C001143 1-31 2018-01-01 2018-12-31 C001143 9-17 2018-01-01 2018-12-31 C001143 1-29 2018-01-01 2018-12-31 C001143 ferc:ElectricPollutionControlFacilitiesMember 2017-12-31 C001143 ferc:ElectricUtilityMember 1-5 2018-01-01 2018-12-31 C001143 ferc:SulfurDioxideMember ferc:AfterThreeYearsMember 2017-12-31 C001143 3-27 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-7 2018-01-01 2018-12-31 C001143 0-11 2018-12-31 C001143 6-8 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 6-31 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 ferc:LandAndRightsMember 0-5 2018-12-31 C001143 1-27 2018-01-01 2018-12-31 C001143 0-26 2018-01-01 2018-12-31 C001143 0-14 2018-12-31 C001143 1-2 2018-01-01 2018-12-31 C001143 0-9 2017-12-31 C001143 5-31 2018-12-31 C001143 9-10 2018-12-31 C001143 4-24 2018-01-01 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 0-29 2018-01-01 2018-12-31 C001143 9-14 2018-12-31 C001143 0-10 2018-01-01 2018-09-30 C001143 7-26 2018-01-01 2018-12-31 C001143 9-32 2018-01-01 2018-12-31 C001143 0-9 2018-01-01 2018-09-30 C001143 7-30 2018-01-01 2018-12-31 C001143 9-50 2018-01-01 2018-12-31 C001143 1-4 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-10 2018-01-01 2018-12-31 C001143 3-19 2018-12-31 C001143 2-13 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-14 2018-01-01 2018-12-31 C001143 0-14 2017-12-31 C001143 3-17 2018-12-31 C001143 0-12 2017-12-31 C001143 1-6 2018-12-31 C001143 7-19 2018-12-31 C001143 1-2 2018-12-31 C001143 ScheduleCorporationsControlledByRespondentAbstract 2018-01-01 2018-12-31 C001143 2-33 2018-01-01 2018-12-31 C001143 4-10 2018-12-31 C001143 5-3 2018-01-01 2018-12-31 C001143 3-48 2018-01-01 2018-12-31 C001143 3-16 2018-01-01 2018-12-31 C001143 1-15 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-17 2018-12-31 C001143 0-4 2018-01-01 2018-12-31 C001143 Coal-0 Neal #3-0 2018-01-01 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 1-18 2018-01-01 2018-12-31 C001143 6-5 2018-01-01 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 ScheduleHydroelectricGeneratingPlantStatisticsAbstract 2018-01-01 2018-12-31 C001143 4-13 2018-01-01 2018-12-31 C001143 2-22 2018-01-01 2018-12-31 C001143 9-49 2018-01-01 2018-12-31 C001143 5-32 2018-01-01 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 0-18 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-6 2018-01-01 2018-12-31 C001143 0-41 2018-01-01 2018-12-31 C001143 ferc:GasUtilityMember 0-10 2017-12-31 C001143 9-14 2018-01-01 2018-12-31 C001143 1 2018-01-01 2018-12-31 C001143 2-19 2018-01-01 2018-12-31 C001143 2-18 2018-01-01 2018-12-31 C001143 0-25 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-8 2018-01-01 2018-12-31 C001143 0-10 2018-12-31 C001143 7-35 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 0-24 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 3-7 2018-12-31 C001143 4-18 2018-01-01 2018-12-31 C001143 0-64 2018-01-01 2018-12-31 C001143 1-8 2018-01-01 2018-12-31 C001143 ferc:LandAndRightsMember 0-9 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 5-35 2018-01-01 2018-12-31 C001143 4-23 2018-01-01 2018-12-31 C001143 ferc:NitrogenOxideMember ferc:AfterThreeYearsMember 2018-12-31 C001143 0-12 2018-01-01 2018-12-31 C001143 0-20 2018-01-01 2018-12-31 C001143 ferc:Quarter2Member 0 2018-01-01 2018-12-31 C001143 3-31 2018-01-01 2018-12-31 C001143 5-11 2018-01-01 2018-12-31 C001143 0-7 2017-12-31 C001143 8-32 2018-12-31 C001143 2-21 2018-01-01 2018-12-31 C001143 0-29 2018-12-31 C001143 4-35 2018-01-01 2018-12-31 C001143 3-8 2018-01-01 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 2-42 2018-01-01 2018-12-31 C001143 6-4 2018-12-31 C001143 8-29 2018-01-01 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 6-24 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 0-12 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 Oil-1 Riverside-1 2018-01-01 2018-12-31 C001143 2-11 2018-01-01 2018-12-31 C001143 9-21 2018-12-31 C001143 9-31 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 4-39 2018-12-31 C001143 0-11 2017-12-31 C001143 6-46 2018-01-01 2018-12-31 C001143 5-36 2018-12-31 C001143 2-48 2018-01-01 2018-12-31 C001143 0-37 2018-01-01 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 5-22 2018-12-31 C001143 0-25 2018-01-01 2018-12-31 C001143 7-32 2018-01-01 2018-12-31 C001143 0-35 2018-01-01 2018-12-31 C001143 8-5 2018-01-01 2018-12-31 C001143 0-43 2018-01-01 2018-12-31 C001143 0-20 2018-01-01 2018-12-31 C001143 5-22 2018-01-01 2018-12-31 C001143 6-1 2018-01-01 2018-12-31 C001143 1-24 2018-12-31 C001143 3-40 2018-01-01 2018-12-31 C001143 0-18 2018-01-01 2018-12-31 C001143 0-2 2018-01-01 2018-12-31 C001143 2-34 2018-12-31 C001143 ferc:ElectricUtilityMember ferc:OtherProductionPlantMember 2018-01-01 2018-12-31 C001143 1-6 2018-01-01 2018-12-31 C001143 0-24 2018-01-01 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 3 2018-01-01 2018-12-31 C001143 1-21 2018-12-31 C001143 0-16 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-42 2018-12-31 C001143 0-19 2018-12-31 C001143 ferc:ElectricUtilityMember 0-2 2018-12-31 C001143 4-33 2018-01-01 2018-12-31 C001143 1-26 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-7 2018-01-01 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 Coal-1 Riverside-1 2018-01-01 2018-12-31 C001143 0-14 2018-12-31 C001143 8-13 2018-01-01 2018-12-31 C001143 Coal-2 Moline-2 2018-01-01 2018-12-31 C001143 9-30 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-6 2018-01-01 2018-12-31 C001143 2-5 2018-01-01 2018-12-31 C001143 1-10 2018-01-01 2018-12-31 C001143 1-29 2018-01-01 2018-12-31 C001143 8-7 2018-01-01 2018-12-31 C001143 3-15 2018-01-01 2018-12-31 C001143 1-24 2018-01-01 2018-12-31 C001143 1-21 2018-01-01 2018-12-31 C001143 7-29 2018-01-01 2018-12-31 C001143 1-19 2018-01-01 2018-12-31 C001143 0-40 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-22 2018-01-01 2018-12-31 C001143 5-39 2018-01-01 2018-12-31 C001143 0-24 2018-01-01 2018-12-31 C001143 ferc:GenerationStudiesMember 1-22 2018-01-01 2018-12-31 C001143 0-16 2018-12-31 C001143 5-23 2018-12-31 C001143 1-7 2018-01-01 2018-12-31 C001143 8-26 2018-01-01 2018-12-31 C001143 1-20 2018-01-01 2018-12-31 C001143 4-30 2018-01-01 2018-12-31 C001143 8-41 2018-01-01 2018-12-31 C001143 1-34 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-13 2018-01-01 2018-12-31 C001143 1-6 2018-01-01 2018-12-31 C001143 5-44 2018-01-01 2018-12-31 C001143 5-20 2018-01-01 2018-12-31 C001143 0-24 2018-01-01 2018-12-31 C001143 2-34 2018-01-01 2018-12-31 C001143 1-25 2018-01-01 2018-12-31 C001143 0-28 2018-01-01 2018-12-31 C001143 8-14 2018-12-31 C001143 0-29 2018-01-01 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 8-26 2018-01-01 2018-12-31 C001143 ferc:LandAndRightsMember 0-13 2018-12-31 C001143 ferc:ElectricUtilityMember 0-6 2017-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 0-8 2018-01-01 2018-12-31 C001143 ferc:DistributionPlantMember ferc:ElectricUtilityMember 2018-01-01 2018-12-31 C001143 2-11 2018-01-01 2018-12-31 C001143 0-3 2018-01-01 2018-12-31 C001143 Walter Scott #3-0 2018-01-01 2018-12-31 C001143 ferc:GenerationStudiesMember 1-27 2018-01-01 2018-12-31 C001143 0-4 2018-12-31 C001143 0-25 2018-01-01 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 0-32 2018-01-01 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 5-6 2018-01-01 2018-12-31 C001143 0-4 2018-12-31 C001143 10-27 2018-01-01 2018-12-31 C001143 0-18 2018-12-31 C001143 1-3 2018-01-01 2018-12-31 C001143 1-23 2018-01-01 2018-12-31 C001143 2-27 2018-12-31 C001143 4-3 2018-01-01 2018-12-31 C001143 0-26 2018-01-01 2018-12-31 C001143 1-18 2018-01-01 2018-12-31 C001143 1-16 2018-01-01 2018-12-31 C001143 8-1 2018-12-31 C001143 4-20 2018-12-31 C001143 1-1 2018-01-01 2018-12-31 C001143 6-12 2018-01-01 2018-12-31 C001143 1 2018-01-01 2018-12-31 C001143 11-26 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-20 2018-01-01 2018-12-31 C001143 3-22 2018-01-01 2018-12-31 C001143 1-29 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 4-32 2018-01-01 2018-12-31 C001143 Coal-1 Pleasant Hill-1 2018-01-01 2018-12-31 C001143 0-7 2018-12-31 C001143 5-12 2018-01-01 2018-12-31 C001143 5-3 2018-01-01 2018-12-31 C001143 ferc:SulfurDioxideMember 2018-12-31 C001143 3-8 2018-12-31 C001143 1-40 2018-12-31 C001143 4-34 2018-12-31 C001143 0-2 2018-01-01 2018-12-31 C001143 0-32 2018-01-01 2018-12-31 C001143 9-37 2018-12-31 C001143 5-26 2018-01-01 2018-12-31 C001143 6-19 2018-12-31 C001143 10-25 2018-01-01 2018-12-31 C001143 0-36 2018-01-01 2018-12-31 C001143 6-13 2018-01-01 2018-12-31 C001143 0-1 2017-12-31 C001143 8-25 2018-12-31 C001143 0-20 2018-01-01 2018-12-31 C001143 Nuclear-2 Quad-Cities-2 2018-01-01 2018-12-31 C001143 4-2 2018-12-31 C001143 4-23 2018-12-31 C001143 6-23 2018-01-01 2018-12-31 C001143 0-18 2018-01-01 2018-12-31 C001143 Oil-2 Coralville-2 2018-01-01 2018-12-31 C001143 1-36 2018-12-31 C001143 1-13 2018-12-31 C001143 8-2 2018-12-31 C001143 6-10 2018-12-31 C001143 ferc:ElectricUtilityMember 0-7 2018-12-31 C001143 0-3 2018-12-31 C001143 ferc:DirectPayrollDistributionMember 0-77 2018-01-01 2018-12-31 C001143 8-1 2018-01-01 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-1 2018-12-31 C001143 1-21 2018-01-01 2018-12-31 C001143 3-4 2018-01-01 2018-12-31 C001143 3-34 2018-01-01 2018-12-31 C001143 ferc:GasUtilityMember 0-13 2018-12-31 C001143 7-21 2018-01-01 2018-12-31 C001143 0-16 2018-01-01 2018-12-31 C001143 1-35 2018-01-01 2018-12-31 C001143 ferc:AprilMember 0 2018-01-01 2018-12-31 C001143 3-31 2018-01-01 2018-12-31 C001143 1-28 2018-01-01 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 6-37 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 0-17 2018-01-01 2018-12-31 C001143 0-38 2018-01-01 2018-12-31 C001143 4-41 2018-01-01 2018-12-31 C001143 0-12 2017-12-31 C001143 0-25 2018-01-01 2018-12-31 C001143 5 2018-01-01 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 0-32 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-26 2018-01-01 2018-12-31 C001143 6-39 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 0-27 2018-12-31 C001143 4-22 2018-01-01 2018-12-31 C001143 2-13 2018-01-01 2018-12-31 C001143 7-3 2018-01-01 2018-12-31 C001143 3-13 2018-01-01 2018-12-31 C001143 1-7 2018-01-01 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 0-19 2017-01-01 2017-12-31 C001143 4-14 2018-01-01 2018-12-31 C001143 3-5 2018-01-01 2018-12-31 C001143 3-1 2018-01-01 2018-12-31 C001143 8-39 2018-12-31 C001143 9-20 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-8 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-4 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 0-33 2018-01-01 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 8-37 2018-12-31 C001143 5-34 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 0-15 2017-12-31 C001143 Neal #4-0 2018-01-01 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 1-9 2018-01-01 2018-12-31 C001143 7-3 2018-12-31 C001143 8-28 2018-12-31 C001143 3-25 2018-12-31 C001143 9-24 2018-12-31 C001143 ferc:SulfurDioxideMember ferc:TwoYearsMember 2018-01-01 2018-12-31 C001143 3-3 2018-01-01 2018-12-31 C001143 1-8 2017-12-31 C001143 0-2 2018-01-01 2018-12-31 C001143 ferc:GasUtilityMember 0-13 2018-01-01 2018-12-31 C001143 10-12 2018-01-01 2018-12-31 C001143 0-5 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1-20 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 3-28 2018-01-01 2018-12-31 C001143 7-2 2018-01-01 2018-12-31 C001143 9-4 2018-12-31 C001143 Gas-0 Ottumwa-0 2018-01-01 2018-12-31 C001143 1-1 2018-01-01 2018-12-31 C001143 1-9 2018-01-01 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 0-12 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 0-10 2017-12-31 C001143 11-36 2018-01-01 2018-12-31 C001143 2-15 2018-12-31 C001143 ferc:ReactiveSupplyAndVoltageMember 2018-01-01 2018-12-31 C001143 0-9 2018-01-01 2018-12-31 C001143 1-7 2018-01-01 2018-12-31 C001143 0-15 2018-12-31 C001143 0-7 2018-01-01 2018-06-30 C001143 ferc:OtherUtilityOrNonutilityMember 0-14 2018-12-31 C001143 0-15 2018-12-31 C001143 3-12 2018-01-01 2018-12-31 C001143 0-38 2018-01-01 2018-12-31 C001143 6-13 2018-01-01 2018-12-31 C001143 9-8 2018-12-31 C001143 0-3 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-7 2018-12-31 C001143 4-25 2018-01-01 2018-12-31 C001143 0-10 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ferc:ElectricUtilityMember 1-2 2018-01-01 2018-12-31 C001143 7-24 2018-01-01 2018-12-31 C001143 1-20 2018-01-01 2018-12-31 C001143 0-23 2017-12-31 C001143 1-11 2018-01-01 2018-12-31 C001143 0-31 2018-12-31 C001143 1-13 2017-12-31 C001143 ferc:NitrogenOxideMember 2018-12-31 C001143 1-36 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-5 2018-01-01 2018-12-31 C001143 3-17 2018-01-01 2018-12-31 C001143 0-34 2018-01-01 2018-12-31 C001143 Gas-2 Coralville-2 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 8-19 2018-01-01 2018-12-31 C001143 5-7 2018-12-31 C001143 2-32 2018-01-01 2018-12-31 C001143 2-39 2018-12-31 C001143 0-15 2018-12-31 C001143 5-13 2018-01-01 2018-12-31 C001143 Gas-1 River Hills-1 2018-01-01 2018-12-31 C001143 9-19 2018-01-01 2018-12-31 C001143 2016-12-31 C001143 ferc:ElectricUtilityMember 0-4 2018-01-01 2018-12-31 C001143 9-35 2018-01-01 2018-12-31 C001143 1-45 2018-01-01 2018-12-31 C001143 4-3 2018-01-01 2018-12-31 C001143 9-22 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-38 2018-12-31 C001143 ferc:Quarter1Member 0 2018-01-01 2018-12-31 C001143 ferc:GenerationStudiesMember 0-31 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 4-4 2018-01-01 2018-12-31 C001143 3-43 2018-01-01 2018-12-31 C001143 1-33 2018-01-01 2018-12-31 C001143 0-7 2018-12-31 C001143 7-27 2018-01-01 2018-12-31 C001143 1-35 2018-01-01 2018-12-31 C001143 3-11 2018-12-31 C001143 0-1 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-32 2018-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 0-11 2018-12-31 C001143 1-11 2018-12-31 C001143 ferc:FebruaryMember 0 2018-01-01 2018-12-31 C001143 6-14 2018-01-01 2018-12-31 C001143 3-14 2018-01-01 2018-12-31 C001143 1-11 2018-01-01 2018-12-31 C001143 4-21 2018-01-01 2018-12-31 C001143 3-25 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 3-5 2018-12-31 C001143 1-23 2018-01-01 2018-12-31 C001143 0-4 2018-01-01 2018-12-31 C001143 1-11 2018-01-01 2018-12-31 C001143 ferc:MayMember 0 2018-01-01 2018-12-31 C001143 2-29 2018-01-01 2018-12-31 C001143 3-39 2018-01-01 2018-12-31 C001143 9-19 2018-01-01 2018-12-31 C001143 6-16 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 3-36 2018-01-01 2018-12-31 C001143 ferc:GenerationStudiesMember 0-23 2018-01-01 2018-12-31 C001143 River Hills-1 2018-01-01 2018-12-31 C001143 3-44 2018-01-01 2018-12-31 C001143 Gas-2 Merl Parr-2 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 ferc:GenerationStudiesMember 0-40 2018-01-01 2018-12-31 C001143 0-19 2018-01-01 2018-12-31 C001143 0-36 2018-01-01 2018-12-31 C001143 0-30 2018-01-01 2018-12-31 C001143 7-31 2018-01-01 2018-12-31 C001143 0-12 2018-12-31 C001143 2-16 2018-01-01 2018-12-31 C001143 9-47 2018-01-01 2018-12-31 C001143 4-37 2018-12-31 C001143 ferc:ElectricUtilityMember 1-9 2018-01-01 2018-12-31 C001143 0-33 2018-01-01 2018-12-31 C001143 0-6 2018-12-31 C001143 6-17 2018-12-31 C001143 1-14 2018-01-01 2018-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 1-2 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-23 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 ferc:LandAndRightsMember 0-11 2018-12-31 C001143 7-16 2018-12-31 C001143 10-33 2018-01-01 2018-12-31 C001143 6-21 2018-01-01 2018-12-31 C001143 0-4 2018-01-01 2018-12-31 C001143 2-13 2018-01-01 2018-12-31 C001143 9-7 2018-12-31 C001143 9-18 2018-01-01 2018-12-31 C001143 2-9 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-12-31 C001143 8-40 2018-01-01 2018-12-31 C001143 1-38 2018-01-01 2018-12-31 C001143 8-39 2018-01-01 2018-12-31 C001143 6-12 2018-01-01 2018-12-31 C001143 3-37 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 1-26 2018-01-01 2018-12-31 C001143 0-25 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-12 2018-01-01 2018-12-31 C001143 4-13 2018-01-01 2018-12-31 C001143 5-7 2018-01-01 2018-12-31 C001143 8-12 2018-01-01 2018-12-31 C001143 10-18 2018-01-01 2018-12-31 C001143 0-53 2018-01-01 2018-12-31 C001143 4-38 2018-12-31 C001143 0-15 2018-01-01 2018-12-31 C001143 9-35 2018-01-01 2018-12-31 C001143 2-36 2018-12-31 C001143 7-29 2018-12-31 C001143 0-43 2018-01-01 2018-12-31 C001143 7-15 2018-12-31 C001143 5-4 2018-01-01 2018-12-31 C001143 0-38 2018-12-31 C001143 3-33 2018-12-31 C001143 2018-01-01 2018-12-31 C001143 1-20 2018-01-01 2018-12-31 C001143 5-20 2018-01-01 2018-12-31 C001143 0-9 2018-12-31 C001143 2-1 2018-01-01 2018-12-31 C001143 ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 1-34 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 0-13 2018-01-01 2018-12-31 C001143 2 2018-01-01 2018-12-31 C001143 8-8 2018-01-01 2018-12-31 C001143 10-22 2018-01-01 2018-12-31 C001143 Oil-2 Merl Parr-2 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-12 2018-12-31 C001143 2-16 2018-12-31 C001143 8-33 2018-01-01 2018-12-31 C001143 0-16 2018-01-01 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 5-38 2018-01-01 2018-12-31 C001143 1-25 2018-01-01 2018-12-31 C001143 0-14 2018-01-01 2018-12-31 C001143 4-24 2018-12-31 C001143 ferc:GasUtilityMember 2017-01-01 2017-12-31 C001143 1-2 2018-12-31 C001143 1-36 2018-01-01 2018-12-31 C001143 2017-01-01 2017-12-31 C001143 4-36 2018-01-01 2018-12-31 C001143 Gas-0 Neal #4-0 2018-01-01 2018-12-31 C001143 3-10 2018-01-01 2018-12-31 C001143 1-6 2018-01-01 2018-12-31 C001143 0-32 2018-01-01 2018-12-31 C001143 7-8 2018-12-31 C001143 ferc:ElectricUtilityMember 0-38 2018-01-01 2018-12-31 C001143 0-5 2018-01-01 2018-12-31 C001143 2-47 2018-01-01 2018-12-31 C001143 0-2 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 0-6 2018-12-31 C001143 6 2018-01-01 2018-12-31 C001143 ferc:ElectricUtilityMember 2017-12-31 C001143 1-22 2018-01-01 2018-12-31 C001143 0-23 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 C001143 2-5 2018-01-01 2018-12-31 C001143 0-19 2018-12-31 C001143 1-7 2018-01-01 2018-12-31 C001143 2-7 2018-01-01 2018-12-31 C001143 0-33 2018-01-01 2018-12-31 C001143 1-11 2018-01-01 2018-12-31 C001143 8-10 2018-01-01 2018-12-31 C001143 0-21 2017-12-31 C001143 5-37 2018-01-01 2018-12-31 C001143 4-12 2018-01-01 2018-12-31 C001143 5-5 2018-12-31 C001143 7-19 2018-01-01 2018-12-31 C001143 8-20 2018-01-01 2018-12-31 C001143 3-35 2018-01-01 2018-12-31 C001143 0-7 2018-01-01 2018-12-31 C001143 5-35 2018-01-01 2018-12-31 C001143 0-21 2018-01-01 2018-12-31 C001143 0-6 2018-01-01 2018-12-31 C001143 0-10 2018-01-01 2018-03-31 C001143 2-1 2018-01-01 2018-12-31 C001143 0-11 2018-01-01 2018-12-31 utr:kV shares ferc:MVa utr:MWh utr:MW utr:mi iso4217:USD utr:MMBTU pure iso4217:USD utr:MW utr:Btu utr:kWh pure utr:mi utr:kWh iso4217:USD utr:kWh iso4217:USD
THIS FILING IS
Item 1:
An Initial (Original) Submission
OR
Resubmission No.

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

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

MidAmerican Energy Company
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

MidAmerican Energy Company
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)

666 Grand Avenue, Suite 500; P.O. Box 657 Des Moines, IA 50306-0657
05 Name of Contact Person

Thomas B. Specketer
06 Title of Contact Person

Vice President and CFO
07 Address of Contact Person (Street, City, State, Zip Code)

666 Grand Avenue, Suite 500; P.O. Box 657 Des Moines, IA 50306-0657
08 Telephone of Contact Person, Including Area Code

(515) 281-2979
09 This Report is An Original / A Resubmission

(1)
An Original

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

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

Thomas B. Specketer
02 Title

Vice President and CFO
03 Signature

04 Date Signed (Mo, Da, Yr)

03/29/2019
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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
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
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
19
ScheduleConstructionWorkInProgressElectricAbstract
Construction Work in Progress-Electric
216
20
ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract
Accumulated Provision for Depreciation of Electric Utility Plant
219
21
ScheduleInvestmentsInSubsidiaryCompaniesAbstract
Investment of Subsidiary Companies
224
22
ScheduleMaterialsAndSuppliesAbstract
Materials and Supplies
227
23
ScheduleAllowanceInventoryAbstract
Allowances
228
24
ScheduleExtraordinaryPropertyLossesAbstract
Extraordinary Property Losses
230a
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
28
ScheduleMiscellaneousDeferredDebitsAbstract
Miscellaneous Deferred Debits
233
29
ScheduleAccumulatedDeferredIncomeTaxesAbstract
Accumulated Deferred Income Taxes
234
30
ScheduleCapitalStockAbstract
Capital Stock
250
31
ScheduleOtherPaidInCapitalAbstract
Other Paid-in Capital
253
32
ScheduleCapitalStockExpenseAbstract
Capital Stock Expense
254b
33
ScheduleLongTermDebtAbstract
Long-Term Debt
256
34
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract
Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax
261
35
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract
Taxes Accrued, Prepaid and Charged During the Year
262
36
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract
Accumulated Deferred Investment Tax Credits
266
37
ScheduleOtherDeferredCreditsAbstract
Other Deferred Credits
269
38
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract
Accumulated Deferred Income Taxes-Accelerated Amortization Property
272
39
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract
Accumulated Deferred Income Taxes-Other Property
274
40
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract
Accumulated Deferred Income Taxes-Other
276
41
ScheduleOtherRegulatoryLiabilitiesAbstract
Other Regulatory Liabilities
278
42
ScheduleElectricOperatingRevenuesAbstract
Electric Operating Revenues
300
43
ScheduleRegionalTransmissionServiceRevenuesAbstract
Regional Transmission Service Revenues (Account 457.1)
302
44
ScheduleSalesOfElectricityByRateSchedulesAbstract
Sales of Electricity by Rate Schedules
304
45
ScheduleSalesForResaleAbstract
Sales for Resale
310
46
ScheduleElectricOperationsAndMaintenanceExpensesAbstract
Electric Operation and Maintenance Expenses
320
47
SchedulePurchasedPowerAbstract
Purchased Power
326
48
ScheduleTransmissionOfElectricityForOthersAbstract
Transmission of Electricity for Others
328
49
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract
Transmission of Electricity by ISO/RTOs
331
N/A
50
ScheduleTransmissionOfElectricityByOthersAbstract
Transmission of Electricity by Others
332
51
ScheduleMiscellaneousGeneralExpensesAbstract
Miscellaneous General Expenses-Electric
335
52
ScheduleDepreciationDepletionAndAmortizationAbstract
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
336
53
ScheduleRegulatoryCommissionExpensesAbstract
Regulatory Commission Expenses
350
54
ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract
Research, Development and Demonstration Activities
352
55
ScheduleDistributionOfSalariesAndWagesAbstract
Distribution of Salaries and Wages
354
56
ScheduleCommonUtilityPlantAndExpensesAbstract
Common Utility Plant and Expenses
356
N/A
57
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract
Amounts included in ISO/RTO Settlement Statements
397
58
SchedulePurchasesSalesOfAncillaryServicesAbstract
Purchase and Sale of Ancillary Services
398
59
ScheduleMonthlyTransmissionSystemPeakLoadAbstract
Monthly Transmission System Peak Load
400
60
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract
Monthly ISO/RTO Transmission System Peak Load
400a
N/A
61
ScheduleElectricEnergyAccountAbstract
Electric Energy Account
401a
62
ScheduleMonthlyPeakAndOutputAbstract
Monthly Peaks and Output
401b
63
ScheduleSteamElectricGeneratingPlantStatisticsAbstract
Steam Electric Generating Plant Statistics
402
64
ScheduleHydroelectricGeneratingPlantStatisticsAbstract
Hydroelectric Generating Plant Statistics
406
N/A
65
SchedulePumpedStorageGeneratingPlantStatisticsAbstract
Pumped Storage Generating Plant Statistics
408
N/A
66
ScheduleGeneratingPlantStatisticsAbstract
Generating Plant Statistics Pages
410
0
ScheduleEnergyStorageOperationsLargePlantsAbstract
Energy Storage Operations (Large Plants)
414
67
ScheduleTransmissionLineStatisticsAbstract
Transmission Line Statistics Pages
422
68
ScheduleTransmissionLinesAddedAbstract
Transmission Lines Added During Year
424
69
ScheduleSubstationsAbstract
Substations
426
70
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract
Transactions with Associated (Affiliated) Companies
429
71
FootnoteDataAbstract
Footnote Data
450
StockholdersReportsAbstract
Stockholders' Reports (check appropriate box)
Stockholders' Reports Check appropriate box:

Two copies will be submitted

No annual report to stockholders is prepared


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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.

Thomas B. Specketer, Vice President and Chief Financial Officer 666 Grand Avenue, Suite 500; P.O. Box 657 Des Moines, IA 50306-0657

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.

Iowa - July 18, 1994

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.

None

(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.

Iowa - Electric and Gas Illinois - Electric and Gas South Dakota - Electric and Gas Nebraska - Gas
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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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.
Controlling Corporation: MHC Inc. (owns 100% of MidAmerican Energy Company) Manner and Extent of Control: 100% Common Stock Ownership Controlling Corporation: MidAmerican Funding, LLC (owns 100% of MHC Inc.) Manner and Extent of Control: 100% Common Stock Ownership Controlling Corporation: Berkshire Hathaway Energy Company (owns 100% of MidAmerican Funding, LLC) Manner and Extent of Control: Sole Member Controlling Corporation: Berkshire Hathaway Inc. (owns 90.9% of Berkshire Hathaway Energy Company) Manner and Extent of Control: 90.9% Common Stock Ownership


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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 CEO
Adam L. Wright
(a)
1,020,569
2
Sr. Vice President, General Counsel, & Corp. Secretary
Robert B. Berntsen
481,062
3
Senior Vice President & Environmental Comp. Officer
Cathy S. Woollums
109,148
4
Vice President
Michael Fehr
293,782
5
Vice President and Secretary
Paul J. Leighton
81,827
6
Vice President and Chief Financial Officer
Thomas B. Specketer
316,538
7
Vice President
James W. Dougherty
317,317
8
Vice President and Associate General Counsel
Jon A. Andreasen
754,894
9
Vice President
Barry Campbell
103,560
10
Assistant Secretary
Jeffery B. Erb
21,914
11
Vice President
Jeffery J. Gust
467,368
12
Vice President
Michael A. Gehringer
290,779
13
Treasurer
James C. Galt
94,403
14
Vice President
Kathryn M. Kunert
109,354
15
Vice President
Michael S. Hindman
248,997
16
Vice President
Rich G. Lovig
204,071
17
Vice President
Jennifer McIvor
183,772
18
Vice President
Spencer T. Moore
424,772
19
Vice President
Mark D. Woofter
262,742


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: OfficerSalary

Salary information represents MidAmerican Energy Company's share of the total W-2 wages paid to the officer.

 

Retired during 2018:

Paul J. Leighton July 13, 2018

Steven R. Evans May 31, 2018


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Adam L. Wright
MidAmerican Energy Company
2
President & CEO
666 Grand Avenue, Suite 500, P.O. Box 657
3
Des Moines, IA 50306-0657
4
Thomas B. Specketer
MidAmerican Energy Company
5
Vice President & CFO
666 Grand Avenue, Suite 500, P.O. Box 657
6
Des Moines, IA 50306-0657
7
Rob B. Berntsen
MidAmerican Energy Company
8
Sr. Vice President, General Counsel, & Corp. Secretary
666 Grand Avenue, Suite 500, P.O Box 657
9
Des Moines, IA 50306-0657


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
MW ISO FERC Electric Tariff Fourth Revised Vol. 1
ER09-1252-000
2
MW ISO FERC Electric Tariff Fourth Revised Vol. 1
ER09-1779-000
3
MW ISO FERC Electric Tariff Fourth Revised Vol. 1
ER10-1492-000
4
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER10-1997-000
5
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER10-1997-001
6
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER11-2700-000
7
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER11-2700-004
8
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER11-3251-000
9
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER11-3704-000
10
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER12-242-000
11
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER12-297-000
12
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER12-310-000
13
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER12-578-000
14
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER12-1667-000
15
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER13-307-000
16
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER13-674-000
17
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER13-674-002
18
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER13-1547-000
19
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER13-1827-000
20
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ERE13-674-000
21
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER13-1169-000
22
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER13-1169-001
23
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER13-1186-000
24
MW ISO FERC Electric Tariff Fifth Revised Vol. 1
ER13-1187-000
25
Midcontinent Independent Sys Oper FERC Elec Tariff
ER13-2379-000
26
Midcontinent Independent Sys Oper FERC Elec Tariff
ER13-2379-003
27
Midcontinent Independent Sys Oper FERC Elec Tariff
ER14-102-000
28
Midcontinent Independent Sys Oper FERC Elec Tariff
ER14-421-000
29
Midcontinent Independent Sys Oper FERC Elec Tariff
ER14421-001
30
Midcontinent Independent Sys Oper FERC Elec Tariff
ER14-260-000
31
Midcontinent Independent Sys Oper FERC Elec Tariff
ER14-261-000
32
Midcontinent Independent Sys Oper FERC Elec Tariff
ER14-649-000
33
Midcontinent Independent Sys Oper FERC Elec Tariff
ER14-2468-000
34
Midcontinent Independent Sys Oper FERC Elec Tariff
ER12-480-006
35
Midcontinent Independent Sys Oper FERC Elec Tariff
ER14-421-000
36
Midcontinent Independent Sys Oper FERC Elec Tariff
ER15-142-000
37
Midcontinent Independent Sys Oper FERC Elec Tariff
ER15-277-000
38
Midcontinent Independent Sys Oper FERC Elec Tariff
ER15-358-000
39
Midcontinent Independent Sys Oper FERC Elec Tariff
ER12-480-007
40
Midcontinent Independent Sys Oper FERC Elec Tariff
ER13-2379-004
41
Midcontinent Independent Sys Oper FERC Elec Tariff
ER15-1067-000
42
Midcontinent Independent Sys Oper FERC Elec Tariff
ER15-1210-000
43
Midcontinent Independent Sys Oper FERC Elec Tariff
ER15-1490-000
44
Midcontinent Independent Sys Oper FERC Elec Tariff
ER15-1689-000
45
Midcontinent Independent Sys Oper FERC Elec Tariff
ER15-1067-001
46
Midcontinent Independent Sys Oper FERC Elec Tariff
ER16-16-000
47
Midcontinent Independent Sys Oper FERC Elec Tariff
ER16-314-000
48
Midcontinent Independent Sys Oper FERC Elec Tariff
ER15-2364-000
49
Midcontinent Independent Sys Oper FERC Elec Tariff
ER16-18-000
50
Midcontinent Independent Sys Oper FERC Elec Tariff
ER16-392-000
51
Midcontinent Independent Sys Oper FERC Elec Tariff
ER16-1313-000
52
Midcontinent Independent Sys Oper FERC Elec Tariff
ER16-1322-000
53
Midcontinent Independent Sys Oper FERC Elec Tariff
ER16-1333-000
54
Midcontinent Independent Sys Oper FERC Elec Tariff
ER16-1534-000
55
Midcontinent Independent Sys Oper FERC Elec Tariff
ER16-2417-000
56
Midcontinent Independent Sys Oper FERC Elec Tariff
ER17-893-000
57
Midcontinent Independent Sys Oper FERC Elec Tariff
ER18-1010-000


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
  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
03/14/2018
ER18-1010
Attach. O Annual Informational Filing
MISO FERC Electric Tariff


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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.

 

The franchises below were acquired without the payment of consideration.

 

 

 

 

 

 

 

 

 

 

 

 

 

Town

Term

Service

New/Renewal

 

 

 

 

 

 

 

 

 

 

 

1st Quarter

Bronson, IA

25 Years

Electric

Renewal

 

 

 

 

Doon, IA

25 Years

Electric

Renewal

 

 

 

 

 

 

 

 

 

 

 

2nd Quarter

Battle Creek, IA

25 Years

Electric & Gas

Renewal

 

 

 

 

Ely, IA

25 Years

Gas

Renewal

 

 

 

 

Harvey, IA

25 Years

Electric & Gas

Renewal

 

 

 

 

Nashua, IA

25 Years

Electric & Gas

Renewal

 

 

 

 

Oyens, IA

25 Years

Electric

Renewal

 

 

 

 

Tiffin, IA

25 Years

Gas

Renewal

 

 

 

 

 

 

 

 

 

 

 

3rd Quarter

De Soto, IA

25 Years

Electric & Gas

Renewal

 

 

 

 

Griswold, IA

25 Years

Electric & Gas

Renewal

 

 

 

 

LuVerne, IA

25 Years

Electric

Renewal

 

 

 

 

Patterson, IA

25 Years

Electric

Renewal

 

 

 

 

W. Des Moines, IA

20 Years

Electric & Gas

Renewal

 

 

 

 

 

 

 

 

 

 

 

4th Quarter

 

 

 

 

 

 

 

 

Danbury, IA

25 Years

Electric & Gas

Renewal

 

 

 

 

Doon, IA

25 Years

Electric

Renewal

 

 

 

 

Emmetsburg, IA

10 Years

Electric

Renewal

 

 

 

 

Mondamin, IA

25 Years

Electric

Renewal

 

 

 

 

Stanton, IA

25 Years

Gas

Renewal

 

 

 

 

Yankton, SD

20 Years

Gas

Renewal

 

 

 

 

 

 

 

 

 

2.

 

None

 

 

 

 

 

 

 

 

 

 

 

 

 

3.

 

None

 

 

 

 

 

 

 

 

 

 

 

 

 

4.

 

None

 

 

 

 

 

 

 

 

 

 

 

 

 

5.

 

None

 

 

 

 

 

 

 

 

 

 

 

 

 

6.

 

Pursuant to a FERC order granted in docket number ES 18-38-000 on June 29, 2018 and effective August 1, 2018,

 

 

MidAmerican Energy has authorization to issue promissory notes and other unsecured short-term indebtedness in

 

 

amount not to exceed $1.305 billion through July 31, 2020. As of December 31, 2018, MidAmerican Energy has

 

 

 

$240 million of commercial paper outstanding pursuant to this order.

 

 

 

 

 

 

 

 

 

 

7.

 

None

 

 

 

 

 

 

 

 

 

 

 

 

 

8.

 

The following compensation increases were received by MidAmerican Energy Company employees during 2018:

 

 

 

 

 

 

 

 

 

 

 

 

Effective

 

Est. Annual

 

 

 

Type

 

Date

Percent

Cost

 

 

 

Salaried

 

1/1/2018

2.18%

$ 3,263,036

 

 

 

Consolidated IBEW

 

5/1/2018

2.00%

$ 1,272,311

 

 

 

Fort Madison Gas Techs

9/1/2018

2.00%

$ 2,630

 

 

 

Sioux Falls Union

 

10/1/2018

2.00%

$ 15,687

 

 

 

 

 

 

 

 

 

9.

 

MidAmerican Energy is party to a variety of legal actions arising out of the normal course of business. Plaintiffs

 

 

occasionally seek punitive or exemplary damages. MidAmerican Energy does not believe that such normal and

 

 

routine litigation will have a material impact on its financial results.

 

 

 

 

 

 

 

 

 

 

10.

 

On January 1, 2018 MidAmerican Energy Company adopted Accounting Standards Update (ASU) No. 2017-07 which

 

 

resulted in a change in the presentation of pension and other post-retirement costs for reporting under generally

 

 

 

accepted accounting principles (GAAP). The amendments in this ASU require that an employer report the service cost

 

 

component of pension and PBOP costs with other compensation costs arising from services rendered by employees

 

 

during the period. Additionally, based on this ASU, these costs generally fall under a subtotal of income from operations

 

 

for GAAP financial reporting. The other components of pension and postretirement benefits other than pensions (PBOP)

 

 

costs are required to be presented in the income statement separately from the service cost component and outside a

 

 

subtotal of income from operations. The amendments in this ASU also allow only the service cost component to be

 

 

eligible for capitalization when all of the other normal criteria for capitalization under GAAP are met.

 

 

 

 

 

 

 

 

 

 

 

In accordance with ASU No. 2017-07, and as allowed by the Commission pursuant to Docket No. AI18-1-000,

 

 

MidAmerican Energy Company changed its capitalization practices beginning January 1, 2018 to include only the service

 

 

cost components of pension and other post-retirement expense to be eligible for capitalization, and exclude non-service

 

 

cost components from costs eligible for capitalization. The impact of this change was not considered material.

 

 

 

 

 

 

 

 

11.

 

None

 

 

 

 

 

 

 

 

 

 

 

 

 

12.

 

None

 

 

 

 

 

 

 

 

 

 

 

 

 

13.

 

Name

 

Title

 

Title Role

Role Start Date

 

 

Erb, Jeffery B.

 

Assistant Secretary

 

Officer

5/9/2018

 

 

Hale, Jonathan D.

 

Vice President, Taxation

Officer

5/9/2018

 

 

Woofter, Mark D.

 

Vice President

 

Officer

1/10/2018

 

 

Wright, Adam L.

 

President & CEO

 

Director

1/10/2018

 

 

 

 

 

 

 

 

14.

 

Not Applicable

 

 

 

 


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
20,886,039,850
18,793,024,845
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200
1,032,184,664
794,068,960
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Enter Total of lines 2 and 3)
21,918,224,514
19,587,093,805
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)
200
6,719,672,910
6,297,131,908
6
UtilityPlantNet
Net Utility Plant (Enter Total of line 4 less 5)
15,198,551,604
13,289,961,897
7
NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication
Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)
202
2,556,935
2,317,276
8
NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly
Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9
NuclearFuelAssembliesInReactorMajorOnly
Nuclear Fuel Assemblies in Reactor (120.3)
141,875,897
145,697,038
10
SpentNuclearFuelMajorOnly
Spent Nuclear Fuel (120.4)
51,518,306
47,495,730
11
NuclearFuelUnderCapitalLeases
Nuclear Fuel Under Capital Leases (120.6)
12
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies
(Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)
202
146,493,325
145,098,821
13
NuclearFuelNet
Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
49,457,813
50,411,223
14
UtilityPlantAndNuclearFuelNet
Net Utility Plant (Enter Total of lines 6 and 13)
15,248,009,417
13,340,373,120
15
OtherElectricPlantAdjustments
Utility Plant Adjustments (116)
16
GasStoredUndergroundNoncurrent
Gas Stored Underground - Noncurrent (117)
17
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
18
NonutilityProperty
Nonutility Property (121)
6,998,730
6,873,777
19
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Prov. for Depr. and Amort. (122)
672,432
643,409
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)
210,205,771
212,974,492
25
SinkingFunds
Sinking Funds (125)
26
DepreciationFund
Depreciation Fund (126)
27
AmortizationFundFederal
Amortization Fund - Federal (127)
28
OtherSpecialFunds
Other Special Funds (128)
582,052,871
721,839,425
29
SpecialFunds
Special Funds (Non Major Only) (129)
30
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
(a)
117,535
31
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
32
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Lines 18-21 and 23-31)
798,702,475
941,044,285
33
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
34
CashAndWorkingFunds
Cash and Working Funds (Non-major Only) (130)
35
Cash
Cash (131)
36
SpecialDeposits
Special Deposits (132-134)
37
WorkingFunds
Working Fund (135)
160,590
159,700
38
TemporaryCashInvestments
Temporary Cash Investments (136)
6,930
171,478,632
39
NotesReceivable
Notes Receivable (141)
40
CustomerAccountsReceivable
Customer Accounts Receivable (142)
168,382,615
140,154,699
41
OtherAccountsReceivable
Other Accounts Receivable (143)
57,357,309
42,941,892
42
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
6,896,242
7,448,997
43
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
44
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Assoc. Companies (146)
27,765,785
76,267,215
45
FuelStock
Fuel Stock (151)
227
54,794,331
119,853,771
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
117,537,618
96,053,789
49
Merchandise
Merchandise (155)
227
77,718
78,996
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
834,181
899,115
53
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
228
54
StoresExpenseUndistributed
Stores Expense Undistributed (163)
227
6,511,714
3,982,345
55
GasStoredCurrent
Gas Stored Underground - Current (164.1)
24,699,909
24,603,292
56
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57
Prepayments
Prepayments (165)
21,149,873
17,741,348
58
AdvancesForGas
Advances for Gas (166-167)
59
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
38,593
60
RentsReceivable
Rents Receivable (172)
61
AccruedUtilityRevenues
Accrued Utility Revenues (173)
143,463,926
159,975,486
62
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
63
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
2,786,833
5,268,641
64
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
(b)
117,535
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)
618,515,555
852,048,517
68
DeferredDebitsAbstract
DEFERRED DEBITS
69
UnamortizedDebtExpense
Unamortized Debt Expenses (181)
35,227,046
31,547,728
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
454,316,409
364,848,139
73
PreliminarySurveyAndInvestigationCharges
Prelim. Survey and Investigation Charges (Electric) (183)
3,848,652
3,441,756
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)
596,597
573,889
77
TemporaryFacilities
Temporary Facilities (185)
736,448
649,380
78
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
75,146,729
118,578,054
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)
10,916,872
12,107,212
82
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234
(c)
434,043,681
451,261,769
83
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
84
DeferredDebits
Total Deferred Debits (lines 69 through 83)
1,014,832,434
983,007,927
85
AssetsAndOtherDebits
TOTAL ASSETS (lines 14-16, 32, 67, and 84)
17,680,059,881
16,116,473,849


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: DerivativeInstrumentAssetsLongTerm
Duplicate fact discrepancy. Schedule: 110 - Schedule - Comparative Balance Sheet - Assets And Other Debits, Row: 64, Column: c, Value: 0
(b) Concept: DerivativeInstrumentAssetsLongTerm
Duplicate fact discrepancy. Schedule: 110 - Schedule - Comparative Balance Sheet - Assets And Other Debits, Row: 64, Column: c, Value: 0
(c) Concept: AccumulatedDeferredIncomeTaxes

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

ADIT-190

Total

Gas, Prod

Only

 

 

 

 

Or Other

Transmission

Plant

Labor

 

 

Related

Related

Related

Related

 

 

Retail

 

 

 

 

 

 

 

 

 

Regulated

 

 

 

 

 

ARO Liability

44,589,272

44,589,272

 

 

 

Reserve for Bad Debts

2,159,915

2,159,915

 

 

 

Accrued Vacation

5,144,530

2,651,891

 

 

2,492,639

Deferred Compensation - Non Current

24,581,928

12,754,722

 

 

11,827,207

LTIP Mark to Mkt Gain / Loss - Inc Stmt

(602,791)

(312,745)

 

 

(290,046)

LT Incentive Plan - non current

5,065,312

2,628,217

 

 

2,437,095

Accrued Liability - Emission Fees

508,323

508,323

 

 

 

Accrued Non Current Liability

(82,795)

210,394

 

(293,189)

 

Deferred Compensation - Current

2,910,115

1,509,959

 

 

1,400,156

Deferred MVP Transmission O/U

(1,655,721)

 

(1,655,721)

 

 

Deferred Severance

17,635

12,091

 

 

5,544

Derivative Hedge - Loss

5,395,984

5,395,984

 

 

 

Gas Contracts Liability

167,827

167,827

 

 

 

Gas Inventory

2,435,004

2,435,004

 

 

 

Gross-up on Refundable Advances (CIAC)

11,435

11,435

 

 

 

State NOL Carryforwards

36,174,557

4,818,909

 

31,355,649

 

Kansas Property Tax Reserve

69,183

69,183

 

 

 

LT Services Agreement

7,786,747

7,786,747

 

 

 

Nuclear Decommissioning

3,420

3,420

 

 

 

OPEB Liability

10,553,169

2,954,888

 

 

7,598,281

Pension Liability

1,657,568

464,119

 

 

1,193,449

Pension Unrecognized Gain / Loss - FAS 158 Inc Stmt

(10,114,771)

(5,251,833)

 

 

(4,862,938)

QCS Nuclear Fuel

939,327

939,327

 

 

 

Refund Accrual

3,451,961

1,420,800

2,031,160

 

 

Renewable Advantage- Deferred Credit

67,797

67,797

 

 

 

Reserve for Public Liability

232,266

3,217

 

229,050

 

RL - ARO

42,292,308

42,292,308

 

 

 

RL - Electric Contracts

10,333

10,333

 

 

 

RL - Iowa Revenue Sharing 2

20,860,888

 

 

20,860,888

 

RL - MFG Gas

1,917,805

1,917,805

 

 

 

RL - Nuclear Self Insurance Reserve

1,625,512

1,625,512

 

 

 

RL - QC Station Outage Reserve

2,479,204

2,479,204

 

 

 

SERP Liab

5,103,927

1,429,100

 

 

3,674,827

Transmission - Deferred Credit

3,565

 

3,565

 

 

Unbilled Revenue

8,985,907

8,985,907

 

 

 

Workers Compensation

1,954,709

1,032,868

 

 

921,841

 

 

 

 

 

 

Nonregulated

 

 

 

 

 

Contribution in Aid of Construction

62,986,543

15,224,749

 

47,761,794

 

Debt AFUDC

(1,504)

(1,504)

 

 

 

State NOL Carryforward

3,529,494

545,100

 

2,984,394

 

Federal Tax Depreciation - CIAC

(34,625,640)

(8,527,174)

 

(26,098,466)

 

Gross-up on Refundable Advances (CIAC)

2,531,751

939,028

 

1,592,724

 

State Charitable Contribution Carryforward

45,188

6,649

 

38,539

 

Investment Impairment

13,657

13,657

 

 

 

Prior Year State Tax Pmts/Receipts

101

-

 

101

 

RL - EADIT Carry Charge

8,242

8,242

 

 

 

State Tax Depreciation - CIAC

(8,025,528)

(1,948,939)

 

(6,076,589)

 

 

 

 

 

 

 

FAS109 - Reg Liability

171,384,730

171,384,730

 

 

 

RA - FIN 48

9,495,293

9,495,293

 

 

 

 

 

 

 

 

 

Subtotal - p234

434,043,682

334,911,729

379,005

72,354,893

26,398,055

Less FASB 109 (ASC 740)

180,880,024

180,880,024

-

-

-

Less FASB 106 (ASC 740)

 

 

 

 

 

Total

253,163,658

154,031,705

379,005

72,354,893

26,398,055


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
564,725,056
564,725,056
3
PreferredStockIssued
Preferred Stock Issued (204)
250
4
CapitalStockSubscribed
Capital Stock Subscribed (202, 205)
5
StockLiabilityForConversion
Stock Liability for Conversion (203, 206)
6
PremiumOnCapitalStock
Premium on Capital Stock (207)
7
OtherPaidInCapital
Other Paid-In Capital (208-211)
253
1,123,733
1,123,733
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
4,476,219
4,476,219
11
RetainedEarnings
Retained Earnings (215, 215.1, 216)
118
5,885,066,644
5,202,913,757
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)
16
ProprietaryCapital
Total Proprietary Capital (lines 2 through 15)
6,446,439,214
5,764,286,327
17
LongTermDebtAbstract
LONG-TERM DEBT
18
Bonds
Bonds (221)
256
4,370,325,000
3,670,325,000
19
ReacquiredBonds
(Less) Reaquired Bonds (222)
256
20
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256
21
OtherLongTermDebt
Other Long-Term Debt (224)
256
1,056,363,576
1,407,968,666
22
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
4,375,081
5,391,157
23
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Debit (226)
16,221,862
11,473,214
24
LongTermDebt
Total Long-Term Debt (lines 18 through 23)
5,414,841,795
5,072,211,609
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases - Noncurrent (227)
1,507,758
1,602,231
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
7,057,714
7,154,800
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
135,942,963
142,904,125
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
15,884,486
14,537,797
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
12,072,337
7,911,976
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
1,398,816
1,724,690
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
34
AssetRetirementObligations
Asset Retirement Obligations (230)
561,549,974
559,362,462
35
OtherNoncurrentLiabilities
Total Other Noncurrent Liabilities (lines 26 through 34)
735,414,048
735,198,081
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
NotesPayable
Notes Payable (231)
240,000,000
38
AccountsPayable
Accounts Payable (232)
562,741,842
436,629,156
39
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
40
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
47,446,787
60,265,614
41
CustomerDeposits
Customer Deposits (235)
3,116,351
2,942,672
42
TaxesAccrued
Taxes Accrued (236)
262
298,101,375
131,701,628
43
InterestAccrued
Interest Accrued (237)
53,863,647
49,856,330
44
DividendsDeclared
Dividends Declared (238)
45
MaturedLongTermDebt
Matured Long-Term Debt (239)
46
MaturedInterest
Matured Interest (240)
47
TaxCollectionsPayable
Tax Collections Payable (241)
3,762,053
3,295,311
48
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
45,888,456
52,303,153
49
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
94,473
96,942
50
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
3,350,761
8,519,105
51
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
1,398,816
1,724,690
52
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
18,871,056
53
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54
CurrentAndAccruedLiabilities
Total Current and Accrued Liabilities (lines 37 through 53)
1,275,837,985
743,885,221
55
DeferredCreditsAbstract
DEFERRED CREDITS
56
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
47,887,064
45,836,656
57
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
266
20,948,896
22,193,203
58
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
59
OtherDeferredCredits
Other Deferred Credits (253)
269
65,228,833
60,347,283
60
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
911,978,201
977,593,721
61
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reaquired Debt (257)
62
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accum. Deferred Income Taxes-Accel. Amort.(281)
272
70,915,554
68,514,426
63
AccumulatedDeferredIncomeTaxesOtherProperty
Accum. Deferred Income Taxes-Other Property (282)
(a)
2,536,008,462
2,450,516,180
64
AccumulatedDeferredIncomeTaxesOther
Accum. Deferred Income Taxes-Other (283)
(b)
154,559,829
175,891,142
65
DeferredCredits
Total Deferred Credits (lines 56 through 64)
3,807,526,839
3,800,892,611
66
LiabilitiesAndOtherCredits
TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)
17,680,059,881
16,116,473,849


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOtherProperty

ADIT- 282

Total

Gas, Prod

Only

 

 

 

 

Or Other

Transmission

Plant

Labor

 

 

Related

Related

Related

Related

 

 

Retail

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FAS109

424,526,471

424,526,471

 

 

 

Transmission Plant

(253,884,355)

 

(253,884,355)

 

 

General Plant

(75,907,724)

(14,203,465)

 

 

(61,704,259)

Other Plant

(2,630,681,430)

(2,630,681,430)

 

 

 

Plant Related BTL

(61,423)

(61,423)

 

 

 

 

 

 

 

 

 

Subtotal - p275

(2,536,008,461)

(2,220,419,847)

(253,884,355)

-

(61,704,259)

Less FASB 109 Above if not separately removed

424,526,471

424,526,471

 

-

 

Less FASB 106 Above if not separately removed

 

 

 

 

 

Total

(2,960,534,932)

(2,644,946,318)

(253,884,355)

-

(61,704,259)

(b) Concept: AccumulatedDeferredIncomeTaxesOther

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

ADIT-283

Total

Gas, Prod

Only

 

 

 

 

Or Other

Transmission

Plant

Labor

 

 

Related

Related

Related

Related

 

 

Retail

 

 

 

 

 

 

 

 

 

Regulated

 

 

 

 

 

RA - ARO

(44,589,272)

(44,589,272)

 

-

 

ARO Asset

(42,292,308)

(42,292,308)

 

-

 

Billed PGA/EAC

(15,385,666)

(11,287,020)

 

(4,098,646)

 

Deferred Rate Case Expense

(38,812)

(17,307)

 

(21,505)

 

Demand Side Management

(9,400,343)

(9,400,343)

 

 

 

Electric Contracts Asset - NC

(10,333)

(10,333)

 

 

 

Emission Allowances

(257,093)

(257,093)

 

 

 

Gain/Loss on Reacquired Debt

(3,048,847)

(258,218)

 

(2,790,629)

 

State NOL Carryforwards

(7,596,655)

(1,011,971)

 

(6,584,685)

 

FIN 48

(122,497)

30,182

 

(152,679)

 

Prepaid Insurance

(834,502)

(71,336)

 

(763,167)

 

QC Station Writedown

(45,175)

(45,175)

 

 

 

RA - Gas Contracts

(167,827)

(167,827)

 

 

 

RA - Medicare Def Tax

(1,059,464)

(294,427)

 

 

(765,037)

RA - MFG Gas

(1,917,805)

(1,917,805)

 

 

 

RA - OPEB Liab

(10,553,168)

(2,954,887)

 

 

(7,598,281)

RA - Pension Liab

(1,657,568)

(464,119)

 

 

(1,193,449)

RA - QCS Nuclear Fuel

(939,327)

(939,327)

 

 

 

RA - SERP Liab

(5,103,927)

(1,429,100)

 

 

(3,674,827)

RA - Unrealized Loss - Derivative Hedge

(5,395,984)

(5,395,984)

 

 

 

 

 

 

 

 

 

Nonregulated

 

 

 

 

 

State NOL Carryforwards

(741,194)

(114,471)

 

(626,723)

 

Deferred Intercompany Gain

(3,014,351)

 

 

(3,014,351)

 

State Charitable Contribution Carryforward

(9,490)

(1,396)

 

(8,093)

 

FIN 48

(376,100)

(376,100)

 

 

 

Prior Year State Tax Pmts/Receipts

(2,121)

(2,121)

 

 

 

 

 

 

 

 

 

Subtotal - p277

(154,559,829)

(123,267,758)

-

(18,060,477)

(13,231,594)

Less FASB 109

-

-

 

-

 

Less FASB 106

-

 

 

 

 

Total

(154,559,829)

(123,267,758)

-

(18,060,477)

(13,231,594)


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
3,037,068,968
2,827,162,113
2,283,146,985
2,108,154,563
753,921,983
719,007,550
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
320
1,468,936,282
1,387,526,340
875,931,241
817,434,835
593,005,041
570,091,505
5
MaintenanceExpense
Maintenance Expenses (402)
320
248,209,377
246,842,159
233,228,478
231,949,189
14,980,899
14,892,970
6
DepreciationExpense
Depreciation Expense (403)
336
552,631,531
490,361,992
510,321,668
450,682,886
42,309,863
39,679,106
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336
19,164,522
22,979,170
19,164,522
22,979,170
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336
15,100,035
10,666,414
13,262,080
8,839,994
1,837,955
1,826,420
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)
93,901,732
51,018,470
93,901,732
51,018,470
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
94,593,060
98,633,140
94,593,060
98,633,140
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262
138,834,955
132,976,748
120,956,287
111,599,374
17,878,668
21,377,374
15
IncomeTaxesOperatingIncome
Income Taxes - Federal (409.1)
262
277,695,712
477,118,940
287,548,281
485,493,753
9,852,569
8,374,813
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes - Other (409.1)
262
8,006,899
23,319,723
15,124,419
25,945,506
7,117,520
2,625,783
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision for Deferred Income Taxes (410.1)
234, 272
1,046,869,677
975,650,701
887,591,387
859,804,044
159,278,290
115,846,657
18
ProvisionForDeferredIncomeTaxesCreditOperatingIncome
(Less) Provision for Deferred Income Taxes-Cr. (411.1)
234, 272
1,006,643,465
651,460,850
847,053,443
551,268,439
159,590,022
100,192,411
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adj. - Net (411.4)
266
1,244,307
1,244,307
1,103,325
1,103,325
140,982
140,982
20
GainsFromDispositionOfPlant
(Less) Gains from Disp. of Utility Plant (411.6)
21
LossesFromDispositionOfServiceCompanyPlant
Losses from Disp. of Utility Plant (411.7)
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
74
74
74
74
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
24
AccretionExpense
Accretion Expense (411.10)
23,943,999
23,906,236
23,943,999
23,906,236
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)
2,219,408,593
2,090,151,196
1,532,878,792
1,415,769,961
686,529,801
674,381,235
27
NetUtilityOperatingIncome
Net Util Oper Inc (Enter Tot line 2 less 25)
817,660,375
737,010,917
750,268,193
692,384,602
67,392,182
44,626,315
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)
6,429,619
3,062,185
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
5,094,977
2,832,574
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
1,282,396
573,077
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
507,748
1,255,010
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
186,074
132,874
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
37
InterestAndDividendIncome
Interest and Dividend Income (419)
6,779,961
3,719,725
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
53,857,248
41,235,481
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
5,285,519
9,936,046
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
388,571
710,749
41
OtherIncome
TOTAL Other Income (Enter Total of lines 31 thru 40)
68,606,663
55,282,553
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
26,901
9,126
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
8,143
8,143
45
Donations
Donations (426.1)
5,918,925
2,429,752
46
LifeInsurance
Life Insurance (426.2)
6,170,878
13,477,568
47
Penalties
Penalties (426.3)
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Exp. for Certain Civic, Political & Related Activities (426.4)
1,135,991
1,102,634
49
OtherDeductions
Other Deductions (426.5)
4,492,323
3,689,801
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
5,411,405
6,238,112
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262
554,847
291,776
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262
6,283,640
5,826,751
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262
3,374,448
2,309,544
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Inc. Taxes (410.2)
234, 272
1,579,688,963
1,174,747,294
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Cr. (411.2)
234, 272
1,577,641,638
1,172,667,808
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)
7,055,916
5,765,033
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
70,251,174
67,285,698
61
InterestChargesAbstract
Interest Charges
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
219,846,878
207,616,552
63
AmortizationOfDebtDiscountAndExpense
Amort. of Debt Disc. and Expense (428)
3,835,949
3,684,896
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reaquired Debt (428.1)
1,190,340
1,144,544
65
AmortizationOfPremiumOnDebtCredit
(Less) Amort. of Premium on Debt-Credit (429)
1,016,076
1,016,076
66
AmortizationOfGainOnReacquiredDebtCredit
(Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67
InterestOnDebtToAssociatedCompanies
Interest on Debt to Assoc. Companies (430)
68
OtherInterestExpense
Other Interest Expense (431)
1,903,391
3,365,096
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)
20,001,820
15,040,742
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
205,758,662
199,754,270
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
682,152,887
604,542,345
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)
682,152,887
604,542,345


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
5,202,913,757
4,598,371,412
2
ChangesAbstract
Changes
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
4
AdjustmentsToRetainedEarningsCreditAbstract
Adjustments to Retained Earnings Credit
4.1
AdjustmentsToRetainedEarningsCredit
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)
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)
682,152,887
604,542,345
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)
5,885,066,644
5,202,913,757
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)
5,885,066,644
5,202,913,757
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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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)
682,152,887
604,542,345
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
571,796,053
513,341,162
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of - Other (Note 1, page 122)
(a)
66,277,423
62,186,223
5.2
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Depreciation charged to operating expenses
11,222,991
10,338,298
5.3
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Regulatory Debits and Credits [Net]
691,329
47,614,670
8
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
42,273,537
326,269,337
9
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustment (Net)
1,244,307
1,244,307
10
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
(b)
25,355,163
(r)
55,792,644
11
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
(c)
40,950,903
(s)
18,728,275
12
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
(d)
64,934
(t)
110,391
13
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
173,928,867
38,542,945
14
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
(e)
9,053
(u)
144,050
15
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
1,949,625
654,768
16
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
53,857,248
41,235,481
17
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
18
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other (provide details in footnote):
18.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Working Capital - Prepayments and Other Current Liabilities
2,249,949
3,056,618
18.2
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other (Note 2, page 122)
(f)
282,444
29,286,560
22
NetCashFlowFromOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)
1,507,510,721
1,395,029,878
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)
(g)
2,485,151,702
(v)
1,862,840,155
27
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
(h)
22,261,623
(w)
22,478,021
28
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
29
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
(i)
134,537
(x)
323,376
30
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
(j)
53,857,248
(y)
41,235,481
31
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other (provide details in footnote):
31.1
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription
Other (provide details in footnote): Net Cost of Removal of Plant
(k)
39,202,932
22,353,945
31.2
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription
Accrued Additions to Plant
(l)
161,405,522
93,762,635
34
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 26 thru 33)
(m)
2,331,488,024
(z)
1,772,997,381
36
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
37
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
17,005,058
1,885,018
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)
(n)
261,185,020
(aa)
147,472,891
45
ProceedsFromSalesOfInvestmentSecurities
Proceeds from Sales of Investment Securities (a)
223,446,356
136,932,152
46
LoansMadeOrPurchased
Loans Made or Purchased
47
CollectionsOnLoans
Collections on Loans
49
NetIncreaseDecreaseInReceivablesInvestingActivities
Net (Increase) Decrease in Receivables
50
NetIncreaseDecreaseInInventoryInvestingActivities
Net (Increase) Decrease in Inventory
51
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities
Net (Increase) Decrease in Allowances Held for Speculation
52
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
53
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other (provide details in footnote):
53.1
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Other (provide details in footnote):
(o)
43,372,986
5,709,102
57
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)
2,308,848,644
1,775,944,000
59
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
60
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
61
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Long-Term Debt (b)
693,889,000
999,210,250
62
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Preferred Stock
63
ProceedsFromIssuanceOfCommonStockFinancingActivities
Common Stock
64
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other (provide details in footnote):
64.1
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription
Other (provide details in footnote):
50,000
64.2
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription
Debt issuance costs
6,981,424
8,872,491
66
NetIncreaseInShortTermDebt
Net Increase in Short-Term Debt (c)
240,000,000
67
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
70
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total 61 thru 69)
926,957,576
990,337,759
72
PaymentsForRetirementAbstract
Payments for Retirement of:
73
PaymentsForRetirementOfLongTermDebtFinancingActivities
Long-term Debt (b)
(p)
350,426,189
(ab)
255,379,153
74
PaymentsForRetirementOfPreferredStockFinancingActivities
Preferred Stock
75
PaymentsForRetirementOfCommonStockFinancingActivities
Common Stock
76
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
78
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
(ac)
99,000,000
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)
576,531,387
635,958,606
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)
224,806,536
255,044,484
88
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
281,409,944
26,365,460
90
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
(q)
56,603,408
281,409,944


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: NoncashAdjustmentsToCashFlowsFromOperatingActivities

Other amortization:

 

 

 

Asset retirement obligation accretion expense

$ 23,943,999

Nuclear fuel

23,215,032

Utility plant

151,00,035

Debt issue cost and discounts

2,819,874

Loss on reacquired debt

1,190,340

Other

 

8,143

Total

 

$ 66,277,423

(b) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
Original value: -25355163
(c) Concept: NetIncreaseDecreaseInInventoryOperatingActivities
Original value: 40950903
(d) Concept: NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Original value: 64934
(e) Concept: NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Original value: 9053
(f) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities

Cash flows from operating activities - other:

 

 

 

Energy efficiency costs

$ 38,049,994

Provision for rate refunds

4,160,361

Advances for aid in construction, net

2,050,407

Settlements of asset retirement obligations

(27,899,572)

Pension and other postretirement plans

(21,120,125)

Other, net

 

5,041,379

Total

 

$ 282,444

(g) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Original value: -2485151702
(h) Concept: GrossAdditionsToNuclearFuelInvestingActivities
Original value: -22261623
(i) Concept: GrossAdditionsToNonutilityPlantInvestingActivities
Original value: -134537
(j) Concept: AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
Original value: -53857248
(k) Concept: OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Original value: -39202932
(l) Concept: OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Original value: 161405522
(m) Concept: CashOutflowsForPlant
Original value: -2331488024
(n) Concept: PurchaseOfInvestmentSecurities
Original value: -261185020
(o) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities

Details of investing activities- other, net:

 

 

 

 

 

 

 

 

 

 

 

 

Nuclear decommissioning trust

 

 

 

 

$ 29,789,040

Corporate-owned life insurance

 

 

 

 

14,505,188

Other, net

 

 

 

 

 

( 921,242)

Total

 

 

 

 

 

 

$ 43,372,986

(p) Concept: PaymentsForRetirementOfLongTermDebtFinancingActivities
Original value: -350426189
(q) Concept: CashAndCashEquivalents

Details of cash at end of year:

 

 

 

 

 

 

 

 

 

 

 

 

 

Working funds (135)

 

 

 

 

 

$ 160,590

Temporary cash investments (136)

 

 

 

 

6,930

Restricted cash and cash equivalents included in special funds (128)

 

56,435,888

Total cash and cash equivalents

 

 

 

 

$ 56,603,408

 

Supplemental Information

 

 

 

 

 

Interest paid, net of amounts capitalized

 

 

 

$ 197,741,132

 

 

 

 

 

 

 

 

Income taxes paid (received)

 

 

 

 

$ (493,529,000)

(r) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
Original value: -55792644
(s) Concept: NetIncreaseDecreaseInInventoryOperatingActivities
Original value: 18728275
(t) Concept: NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Original value: 110391
(u) Concept: NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Original value: -144050
(v) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Original value: -1862840155
(w) Concept: GrossAdditionsToNuclearFuelInvestingActivities
Original value: -22478021
(x) Concept: GrossAdditionsToNonutilityPlantInvestingActivities
Original value: -323376
(y) Concept: AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
Original value: -41235481
(z) Concept: CashOutflowsForPlant
Original value: -1772997381
(aa) Concept: PurchaseOfInvestmentSecurities
Original value: -147472891
(ab) Concept: PaymentsForRetirementOfLongTermDebtFinancingActivities
Original value: -255379153
(ac) Concept: NetDecreaseInShortTermDebt
Original value: -99000000

Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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.

MIDAMERICAN ENERGY COMPANY

NOTES TO FINANCIAL STATEMENTS

 

 

(1) Organization and Operations

 

MidAmerican Energy Company ("MidAmerican Energy") is a public utility with electric and natural gas operations and is the principal subsidiary of MHC Inc. ("MHC"). MHC is a holding company that conducts no business other than the ownership of its subsidiaries and related corporate services. MHC's nonregulated subsidiaries include Midwest Capital Group, Inc. and MEC Construction Services Co. MHC is the direct wholly owned subsidiary of MidAmerican Funding, LLC, ("MidAmerican Funding"), which is an Iowa limited liability company with Berkshire Hathaway Energy Company ("BHE") as its sole member. BHE is a holding company based in Des Moines, Iowa that owns subsidiaries principally engaged in energy businesses. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

 

 

(2) Summary of Significant Accounting Policies

 

Use of Estimates in Preparation of Financial Statements

 

The preparation of the Financial Statements in conformity with FERC guidelines requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the period. These estimates include, but are not limited to, the effects of regulation; certain assumptions made in accounting for pension and other postretirement benefits; asset retirement obligations ("AROs"); income taxes; unbilled revenue; valuation of certain financial assets and liabilities, including derivative contracts; and accounting for contingencies. Actual results may differ from the estimates used in preparing the Financial Statements.

 

As required by the FERC, operating income in the FERC presentation must exclude certain nonregulated operating revenue and costs and include non-service costs of postretirement benefit plans and income tax expense pertinent to regulated operations, which are included and excluded, respectively, in operating income determined in accordance with accounting principles generally accepted in the United States of America (“GAAP”). Secondly, GAAP requires the offsetting of certain tax related assets and liabilities that are reported separately in accordance with FERC guidelines. Thirdly, MidAmerican Energy has accrued for the costs of removing other electric and gas assets through its depreciation rates and reported these balances in accumulated depreciation in accordance with the FERC guidelines whereas GAAP requires those costs to be reported as a regulatory liability. Finally, FERC guidelines require certain other assets and liabilities, including derivatives, asset retirement obligations and affiliate receivables and payables, to be presented differently than they would be under GAAP. If GAAP were followed, as of December 31, 2018 and 2017, respectively, net utility plant would be increased by $905 million and $861 million; current and accrued assets would be increased by $42 million and $94 million; other property and investments would be decreased by $85 million and $207 million; deferred debits would be decreased by $623 million and $546 million; current and accrued liabilities would be increased by $514 million and $366 million, long-term debt would be decreased by $534 million and $380 million; other noncurrent liabilities and deferred credits would be decreased by $259 million and increased by $216 million; and proprietary capital would remain unchanged.

 

Accounting for the Effects of Certain Types of Regulation

 

MidAmerican Energy's utility operations are subject to the regulation of the Iowa Utilities Board ("IUB"), the Illinois Commerce Commission ("ICC"), the South Dakota Public Utilities Commission, and the Federal Energy Regulatory Commission ("FERC"). MidAmerican Energy's accounting policies and the accompanying Financial Statements conform to GAAP except for the differences noted above applicable to rate-regulated enterprises and reflect the effects of the ratemaking process.


MidAmerican Energy prepares its financial statements in accordance with authoritative guidance for regulated operations, which recognizes the economic effects of regulation. Accordingly, MidAmerican Energy defers the recognition of certain costs or income if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in future regulated rates. Regulatory assets and liabilities are established to reflect the impacts of these deferrals, which will be recognized in earnings in the periods the corresponding changes in regulated rates occur.

 

MidAmerican Energy continually evaluates the applicability of the guidance for regulated operations and whether its regulatory assets and liabilities are probable of inclusion in future regulated rates by considering factors such as a change in the regulator's approach to setting rates from cost-based ratemaking to another form of regulation, other regulatory actions or the impact of competition, that could limit MidAmerican Energy's ability to recover its costs. MidAmerican Energy believes the application of the guidance for regulated operations is appropriate, and its existing regulatory assets and liabilities are probable of inclusion in future regulated rates. The evaluation reflects the current political and regulatory climate at both the federal and state levels. If it becomes no longer probable that the deferred costs or income will be included in future regulated rates, the related regulatory assets and liabilities will be written off to net income, returned to customers or re-established as accumulated other comprehensive income (loss) ("AOCI").

 

Fair Value Measurements

 

As defined under GAAP, fair value is the price that would be received to sell an asset or paid to transfer a liability between market participants in the principal market or in the most advantageous market when no principal market exists. Adjustments to transaction prices or quoted market prices may be required in illiquid or disorderly markets in order to estimate fair value. Different valuation techniques may be appropriate under the circumstances to determine the value that would be received to sell an asset or paid to transfer a liability in an orderly transaction. Market participants are assumed to be independent, knowledgeable, able and willing to transact an exchange and not under duress. Nonperformance or credit risk is considered in determining fair value. Considerable judgment may be required in interpreting market data used to develop the estimates of fair value. Accordingly, estimates of fair value presented herein are not necessarily indicative of the amounts that could be realized in a current or future market exchange.

 

Cash Equivalents and Restricted Cash and Cash Equivalents and Investments

 

Cash equivalents consist of funds invested in money market mutual funds, United States Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted amounts are included in other current property and investments and restricted investments on the Balance Sheets.

 

Investments

 

Fixed Maturity Securities

 

MidAmerican Energy's management determines the appropriate classification of investments in fixed maturity securities at the acquisition date and reevaluates the classification at each balance sheet date. Investments that management does not intend to use or is restricted from using in current operations are presented as noncurrent on the Balance Sheets.

 

Available-for-sale investments are carried at fair value with realized gains and losses, as determined on a specific identification basis, recognized in earnings and unrealized gains and losses recognized in AOCI, net of tax. Realized and unrealized gains and losses on fixed maturity securities in a trust related to the decommissioning of the Quad Cities Generating Station Units 1 and 2 ("Quad Cities Station") are recorded as a net regulatory liability because MidAmerican Energy expects to recover costs for these activities through regulated rates. Trading investments are carried at fair value with changes in fair value recognized in earnings. Held-to-maturity securities are carried at amortized cost, reflecting the ability and intent to hold the securities to maturity. The difference between the original cost and maturity value of a fixed maturity security is amortized to earnings using the interest method.

 

Investments gains and losses arise when investments are sold (as determined on a specific identification basis) or are other-than-temporarily impaired with respect to securities classified as available-for-sale. If the value of a fixed maturity investment declines to below amortized cost and the decline is deemed other than temporary, the amortized cost of the investment is reduced to fair value, with a corresponding charge to earnings. Any resulting impairment loss is recognized in earnings if MidAmerican Energy intends to sell, or expects to be required to sell, the debt security before its amortized cost is recovered. If MidAmerican Energy does not expect to ultimately recover the amortized cost basis even if it does not intend to sell the security, the credit loss component is recognized in earnings and any difference between fair value and the amortized cost basis, net of the credit loss, is reflected in other comprehensive income (loss) ("OCI"). For regulated investments, any impairment charge is offset by the establishment of a regulatory asset to the extent recovery in regulated rates is probable.

Equity Securities

 

All changes in fair value of equity securities in a trust related to the decommissioning of nuclear generation assets are recorded as a net regulatory liability since MidAmerican Energy expects to recover costs for these activities through regulated rates.

 

Allowance for Doubtful Accounts

 

Receivables are stated at the outstanding principal amount, net of an estimated allowance for doubtful accounts. The allowance for doubtful accounts is based on MidAmerican Energy's assessment of the collectibility of amounts owed to it by its customers. This assessment requires judgment regarding the ability of customers to pay or the outcome of any pending disputes. As of December 31, 2018 and 2017, the allowance for doubtful accounts totaled $7 million and is included in receivables, net on the Balance Sheets.

 

Derivatives

 

MidAmerican Energy employs a number of different derivative contracts, including forwards, futures, options, swaps and other agreements, to manage price risk for electricity, natural gas and other commodities, and interest rate risk. Derivative contracts are recorded on the Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. Derivative balances reflect offsetting permitted under master netting agreements with counterparties and cash collateral paid or received under such agreements. Cash collateral received from or paid to counterparties to secure derivative contract assets or liabilities in excess of amounts offset is included in other current assets on the Balance Sheets.

 

Commodity derivatives used in normal business operations that are settled by physical delivery, among other criteria, are eligible for and may be designated as normal purchases or normal sales. Normal purchases or normal sales contracts are not marked to market, and settled amounts are recognized as operating revenue or cost of sales on the Statements of Income.

 

For MidAmerican Energy's derivatives not designated as hedging contracts, the settled amount is generally included in regulated rates. Accordingly, the net unrealized gains and losses associated with interim price movements on contracts that are accounted for as derivatives and probable of inclusion in regulated rates are recorded as regulatory assets and liabilities.

 

Inventories

 

Inventories consist mainly of coal stocks, totaling $51 million and $117 million as of December 31, 2018 and 2017, respectively, materials and supplies, totaling $124 million and $100 million as of December 31, 2018 and 2017, respectively, and natural gas in storage, totaling $24 million as of December 31, 2018 and 2017. The cost of materials and supplies, coal stocks and fuel oil is determined using the average cost method. The cost of stored natural gas is determined using the last-in-first-out method. With respect to stored natural gas, the replacement cost would be $14 million and $22 million higher as of December 31, 2018 and 2017, respectively.

 

Utility Plant, Net

 

General

 

Additions to utility plant are recorded at cost. MidAmerican Energy capitalizes all construction-related material, direct labor and contract services, as well as indirect construction costs. Indirect construction costs include debt allowance for funds used during construction ("AFUDC") and equity AFUDC. The cost of additions and betterments are capitalized, while costs incurred that do not improve or extend the useful lives of the related assets are generally expensed. Additionally, MidAmerican Energy has regulatory arrangements in Iowa in which the carrying cost of certain utility plant has been reduced for amounts associated with electric returns on equity exceeding specified thresholds and retail energy benefits associated with certain wind-powered generation. Amounts expensed under this arrangement are included as a component of depreciation and amortization.

 

Depreciation and amortization for MidAmerican Energy's utility operations are computed by applying the composite or straight-line method based on either estimated useful lives or mandated recovery periods as prescribed by its various regulatory authorities. Depreciation studies are completed by MidAmerican Energy to determine the appropriate group lives, net salvage and group depreciation rates. These studies are reviewed and rates are ultimately approved by the applicable regulatory commission. Net salvage includes the estimated future residual values of the assets and any estimated removal costs recovered through approved depreciation rates. Estimated removal costs are recorded as either a cost of removal regulatory liability or an ARO liability on the Balance Sheets, depending on whether the obligation meets the requirements of an ARO. As actual removal costs are incurred, the associated liability is reduced.

 

The average depreciation and amortization rates applied to depreciable utility plant for the years ended December 31 were as follows:

 

2018

 

2017

 

 

 

 

Electric

2.9

%

 

2.6

%

Natural gas

2.8

%

 

2.7

%

 

Generally, when MidAmerican Energy retires or sells a component of utility plant, it charges the original cost, net of any proceeds from the disposition to accumulated depreciation. Any gain or loss on disposals of nonregulated assets is recorded through earnings.

 

Debt and equity AFUDC, which represent the estimated costs of debt and equity funds necessary to finance the construction of its regulated facilities, is capitalized by MidAmerican Energy as a component of utility plant, with offsetting credits to the Statements of Income. AFUDC is computed based on guidelines set forth by the FERC. After construction is completed, MidAmerican Energy is permitted to earn a return on these costs as a component of the related assets, as well as recover these costs through depreciation expense over the useful lives of the related assets.

 

Asset Retirement Obligations

 

MidAmerican Energy recognizes AROs when it has a legal obligation to perform decommissioning or removal activities upon retirement of an asset. MidAmerican Energy's AROs are primarily related to decommissioning of the Quad Cities Station and obligations associated with its other generating facilities. The fair value of an ARO liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made, and is added to the carrying amount of the associated asset, which is then depreciated over the remaining useful life of the asset. Subsequent to the initial recognition, the ARO liability is adjusted for any revisions to the original estimate of undiscounted cash flows (with corresponding adjustments to utility plant) and for accretion of the ARO liability due to the passage of time. The difference between the ARO liability, the corresponding ARO asset included in utility plant, net and amounts recovered in rates to satisfy such liabilities is recorded as a regulatory asset or liability.

 

Impairment

 

MidAmerican Energy evaluates long-lived assets for impairment, including utility plant, when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable or the assets are being held for sale. Upon the occurrence of a triggering event, the asset is reviewed to assess whether the estimated undiscounted cash flows expected from the use of the asset plus the residual value from the ultimate disposal exceeds the carrying value of the asset. If the carrying value exceeds the estimated recoverable amounts, the asset is written down to the estimated fair value. The impacts of regulation are considered when evaluating the carrying value of regulated assets. For all other assets, any resulting impairment loss is reflected on the Statements of Income.

 

Revenue Recognition

 

MidAmerican Energy uses a single five-step model to identify and recognize revenue from contracts with customers ("Customer Revenue") upon transfer of control of promised goods or services in an amount that reflects the consideration to which MidAmerican Energy expects to be entitled in exchange for those goods and services. MidAmerican Energy records sales, franchise and excise taxes collected directly from customers and remitted directly to the taxing authorities on a net basis on the Statements of Income.

 

A majority of MidAmerican Energy's energy revenue is derived from tariff-based sales arrangements approved by various regulatory commissions. These tariff-based revenues are mainly comprised of energy, transmission, distribution and natural gas and have performance obligations to deliver energy products and services to customers which are satisfied over time as energy is delivered or services are provided. Other revenue consists primarily of revenue recognized in accordance with Accounting Standards Codification ("ASC") 840, "Leases" and amounts not considered Customer Revenue within ASC 606.

 

Revenue from electric and natural gas customers is recognized as electricity or natural gas is delivered or services are provided. Revenue recognized includes billed and unbilled amounts. As of December 31, 2018 and 2017, unbilled revenue was $88 million and $89 million, respectively, and is included in accrued utility revenues on the Balance Sheets.

 

The determination of customer billings is based on a systematic reading of customer meters and applicable rates. At the end of each month, amounts of energy provided to customers since the date of the last meter reading are estimated, and the corresponding unbilled revenue is recorded. Factors that can impact the estimate of unbilled energy include, but are not limited to, seasonal weather patterns, total volumes supplied to the system, line losses, economic impacts and composition of customer classes. Unbilled revenue is reversed in the following month and billed revenue is recorded based on the subsequent meter readings.

 

All of MidAmerican Energy's regulated retail electric and natural gas sales are subject to energy adjustment clauses. MidAmerican Energy also has costs that are recovered, at least in part, through bill riders, including demand-side management and certain transmission costs. The clauses and riders allow MidAmerican Energy to adjust the amounts charged for electric and natural gas service as the related costs change. The costs recovered in revenue through use of the adjustment clauses and bill riders are charged to expense in the same year the related revenue is recognized. At any given time, these costs may be over or under collected from customers. The total under collection included in accrued utility revenues at December 31, 2018 and 2017, was $56 million and $72 million, respectively.

 

Unamortized Debt Premiums, Discounts and Issuance Costs

 

Premiums, discounts and issuance costs incurred for the issuance of long-term debt are amortized over the term of the related financing using the effective interest method.

 

Income Taxes

 

Berkshire Hathaway includes MidAmerican Energy in its consolidated United States federal and Iowa state income tax returns. MidAmerican Energy's provision for income taxes has been computed on a stand-alone basis.

 

Deferred income tax assets and liabilities are based on differences between the financial statement and income tax basis of assets and liabilities using estimated income tax rates expected to be in effect for the year in which the differences are expected to reverse. Changes in deferred income tax assets and liabilities that are associated with components of OCI are charged or credited directly to OCI. Changes in deferred income tax assets and liabilities that are associated with certain property-related basis differences and other various differences that MidAmerican Energy deems probable to be passed on to its customers in most state jurisdictions are charged or credited directly to a regulatory asset or liability and will be included in regulated rates when the temporary differences reverse. Other changes in deferred income tax assets and liabilities are included as a component of income tax expense. Changes in deferred income tax assets and liabilities attributable to changes in enacted income tax rates are charged or credited to income tax expense or a regulatory asset or liability in the period of enactment. Investment tax credits are generally deferred and amortized over the estimated useful lives of the related properties or as prescribed by various regulatory commissions.

 

In determining MidAmerican Energy's income taxes, management is required to interpret complex income tax laws and regulations, which includes consideration of regulatory implications imposed by MidAmerican Energy's various regulatory commissions. MidAmerican Energy's income tax returns are subject to continuous examinations by federal, state and local tax authorities that may give rise to different interpretations of these complex laws and regulations. Due to the nature of the examination process, it generally takes years before these examinations are completed and these matters are resolved. MidAmerican Energy recognizes the tax benefit from an uncertain tax position only if it is more-likely-than-not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the Financial Statements from such a position are measured based on the largest benefit that is more-likely-than-not to be realized upon ultimate settlement. Although the ultimate resolution of MidAmerican Energy’s federal, state and local income tax examinations is uncertain, MidAmerican Energy believes it has made adequate provisions for its income tax positions. The aggregate amount of any additional income tax liabilities that may result from these examinations, if any, is not expected to have a material impact on its financial results. MidAmerican Energy's unrecognized tax benefits are primarily included in taxes accrued and other long-term liabilities on its Balance Sheets. Estimated interest and penalties, if any, related to uncertain tax positions are included as a component of income tax expense on the Statements of Income.

 

Under Federal Tax law, utilities are required to retain their protected excess deferred income taxes arising from decreases in the federal tax rate in order to retain the ability to continue to use accelerated depreciation, and to reverse them over the remaining book life of the associated assets. MidAmerican Energy Company’s excess deferred income tax arising from the passage of the Tax Cuts and Jobs Act in 2017 was calculated by measuring the difference between its accumulated temporary differences as of December 31, 2017, at the Company’s post-tax reform federal statutory income tax rate as compared to the same temporary differences at the Company’s pre-tax reform federal statutory income tax rate. The changes in deferred tax and regulatory liabilities in MidAmerican’s December 31, 2017, FERC Form 1, and described under the Tax Cuts and Jobs Act above were driven primarily, but not solely by, entries reflecting the estimation of the excess accumulated deferred taxes at year-end. The excess deferred income tax balances presented in the table below represent the final excess deferred income tax balances calculated after the completion of MidAmerican’s December 31, 2017, federal income tax return and do not reflect any amortizations recorded during the year ended December 31, 2018. Property related protected and unprotected excess deferred tax balances will be amortized using the Average Rate Assumption Method over the remaining book life of the related assets through account 411.1. Non-property excess deferred income tax balances were reversed to expense at year-end 2017, and no further expense for them will be recorded. For further discussion of the jurisdictional status of tax reform, see the Regulatory Matters section.

 

FERC Account

Protected

Unprotected

Total

Gross Up

Total Regulatory Liability

Acct. 190 Accumulated Deferred Income Taxes

-

-

-

-

-

Acct. 281, Accum Deferred Income Taxes-Accel. Amort

(26,656,122)

(107,626)

(26,763,748)

(10,715,244)

(37,478,992)

Acct. 282, Accum Deferred Income Taxes-Other Property

(1,168,218,187)

(13,144,745)

(1,181,362,932)

(472,975,301)

(1,654,338,233)

Acct. 283, Accum Deferred Income Taxes-Other

-

-

-

-

-

Acct. 182.3, Other Regulatory Assets

-

-

-

-

-

Acct. 254, Other Regulatory Liabilities

-

-

-

-

-

Total Excess Deferred Income Taxes

(1,194,874,309)

(13,252,371)

(1,208,126,680)

(483,690,545)

(1,691,817,225)

 

New Accounting Pronouncements

 

In August 2018, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2018-14, which amends FASB Accounting Standards Codification ("ASC") Topic 715, "Compensation - Retirement Benefits." The amendments in this guidance modify the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The amendments in this guidance remove disclosures that no longer are considered cost beneficial, clarify the specific requirements of disclosures and add disclosure requirements identified as relevant. The updated disclosure requirements make a number of changes to improve the effectiveness of disclosures in the notes to the financial statements. This guidance is effective for annual reporting periods ending after December 15, 2020, with early adoption permitted, and is required to be adopted retrospectively. MidAmerican Energy elected to early adopt ASU No. 2018-14 for period ending December 31, 2018. The adoption did not have a material impact on MidAmerican Energy's Financial Statements and disclosures included within Notes to Financial Statements.

 

 

In February 2016, the FASB issued ASU No. 2016-02, which creates FASB ASC Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. During 2018, the FASB issued several ASUs that clarified the implementation guidance and provided optional transition practical expedients for ASU No. 2016-02 including ASU No. 2018-01 that allows companies to forgo evaluating existing land easements if they were not previously accounted for under ASC Topic 840, "Leases," ASU No. 2018-11 that allows companies to apply the new guidance at the adoption date with the cumulative-effect adjustment to the opening balance of retained earnings recognized in the period of adoption and ASU No. 2018-20 that provides targeted improvements to lessor accounting, such as the handling of sales and other similar taxes. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. MidAmerican Energy adopted this guidance effective January 1, 2019, for all contracts currently in-effect. MidAmerican Energy is finalizing its implementation efforts relative to the new guidance and currently does not believe the adoption of the new guidance will have a material impact on its Financial Statements and disclosures included within Notes to Financial Statements.

 

In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. MidAmerican Energy adopted this guidance effective January 1, 2018, and the adoption did not have a material impact on its Financial Statements and disclosures included within Notes to Financial Statements.

 

In May 2014, the FASB issued ASU No. 2014-09, which created FASB ASC Topic 606, "Revenue from Contracts with Customers" ("ASC 606") and superseded ASC Topic 605, "Revenue Recognition." The guidance replaced industry-specific guidance and established a single five-step model to identify and recognize revenue from contracts with customers ("Customer Revenue"). The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Following the issuance of ASU No. 2014-09, the FASB issued several ASUs that clarified the implementation guidance for ASU No. 2014-09 but did not change the core principle of the guidance. MidAmerican Energy adopted this guidance for all applicable contracts as of January 1, 2018 under a modified retrospective method and the adoption did not have a cumulative effect impact at the date of initial adoption.

 

 

(3) Jointly Owned Utility Facilities

 

Under joint facility ownership agreements with other utilities, MidAmerican Energy, as a tenant in common, has undivided interests in jointly owned generation and transmission facilities. MidAmerican Energy accounts for its proportionate share of each facility, and each joint owner has provided financing for its share of each facility. Operating costs of each facility are assigned to joint owners based on their percentage of ownership or energy production, depending on the nature of the cost. Operating expenses on the Statements of Income include MidAmerican Energy's share of the expenses of these facilities.

 

 

 

 

 

 

 

 

 

 

 

 

The amounts shown in the table below represent MidAmerican Energy's share in each jointly owned facility included in property, plant and equipment, net as of December 31, 2018 (dollars in millions):

 

 

 

 

 

Accumulated

 

Construction

 

Company

 

Plant in

 

Depreciation and

 

Work-in-

 

Share

 

Service

 

Amortization

 

Progress

 

 

 

 

 

 

 

 

Louisa Unit No. 1

88

 

 

$

822

 

 

$

493

 

 

$

8

 

Quad Cities Unit Nos. 1 & 2(1)

25

 

 

723

 

 

407

 

 

10

 

Walter Scott, Jr. Unit No. 3

79

 

 

641

 

 

344

 

 

2

 

Walter Scott, Jr. Unit No. 4(2)

60

 

 

454

 

 

140

 

 

1

 

George Neal Unit No. 4

41

 

 

310

 

 

189

 

 

2

 

Ottumwa Unit No. 1

52

 

 

630

 

 

229

 

 

6

 

George Neal Unit No. 3

72

 

 

442

 

 

230

 

 

3

 

Transmission facilities

Various

 

257

 

 

92

 

 

 

Total

 

 

$

4,279

 

 

$

2,124

 

 

$

32

 

  1. Includes amounts related to nuclear fuel.

  2. Plant in service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling $319 million and $88 million, respectively.

 

 

(4) Regulatory Matters

 

For Illinois rate making, the excess property related deferred taxes arising from the passage of the Tax Cuts and Jobs Act in 2017 will be amortized using the Average Rate Assumption Method (ARAM). For Iowa rate making purposes, the amortization of excess deferred taxes will be retained in a regulatory liability until it is addressed in the company’s next gas and electric rate cases. MidAmerican and South Dakota regulators are currently in discussion on the treatment to be used in regard to the excess deferred taxes allocable to that jurisdiction. For FERC formula rates, the excess deferred taxes for any FERC-only assets will reverse on ARAM, but any excess deferred taxes for assets subject to state regulation will follow the treatment required by that jurisdiction.

 

 

 

 

 

 

 

 

 

 

 

Regulatory assets represent costs that are expected to be recovered in future regulated rates. MidAmerican Energy's regulatory assets reflected on the Balance Sheets consist of the following as of December 31 (in millions):

 

Average

 

 

 

 

 

Remaining Life

 

2018

 

2017

 

 

 

 

 

 

Depreciation deferred

9 years

 

$

197

 

 

$

172

 

Asset retirement obligations(1)

12 years

 

 

160

 

 

 

133

 

Employee benefit plans(2)

14 years

 

62

 

 

38

 

Unrealized loss on regulated derivative contracts

1 year

 

19

 

 

6

 

Other

Various

 

32

 

 

27

 

Total

 

 

$

470

 

 

$

376

 

  1. Amount predominantly relates to asset retirement obligations for fossil-fueled and wind-powered generating facilities. Refer to Note 10 for a discussion of asset retirement obligations.

  2. Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.

 

MidAmerican Energy had regulatory assets not earning a return on investment of $269 million and $200 million as of December 31, 2018 and 2017, respectively.

 

Regulatory liabilities represent income to be recognized or amounts to be returned to customers in future periods. MidAmerican Energy's regulatory liabilities reflected on the Balance Sheets consist of the following as of December 31 (in millions):

 

Average

 

 

 

 

 

Remaining Life

 

2018

 

2017

 

 

 

 

 

 

Deferred income taxes(1)

29 years

 

$

626

 

 

$

681

 

Asset retirement obligations(2)

34 years

 

160

 

 

173

 

Employee benefit plans(3)

N/A

 

 

 

41

 

Pre-funded AFUDC on transmission MVPs(4)

54 years

 

36

 

 

35

 

Iowa electric revenue sharing accrual(5)

1 year

 

70

 

 

26

 

Other

Various

 

20

 

 

17

 

Total

 

 

$

912

 

 

$

973

 

 

(1) Amounts primarily represent income tax liabilities primarily related to the federal tax rate change from 35% to 21% that are probable to be passed on to customers, offset by income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously passed on to customers and will be included in regulated rates when the temporary differences reverse. See Note 8 for further discussion of 2017 Tax Reform impacts.

(2) Amount predominantly represents the excess of nuclear decommission trust assets over the related asset retirement obligation. Refer to Note 10 for a discussion of asset retirement obligations.

  1. Represents amounts not yet recognized as a component of net periodic benefit cost that are to be returned to customers in future periods when recognized.

  2. Represents AFUDC accrued on transmission MVPs that is deducted from rate base as a result of the inclusion of related construction work-in-progress in rate base.

  3. Represents current-year accruals under a regulatory arrangement in Iowa in which equity returns exceeding specified thresholds reduce utility plant upon final determination.

 

(5) Other Property and Investments

 

Other Property and Investments consists of the following amounts as of December 31 (in millions):

 

2018

 

2017

 

 

 

 

Nuclear decommissioning trust

$

504

 

 

$

515

 

Rabbi trusts

191

 

 

198

 

Pension asset

21

 

 

97

 

Nonregulated property, net of accumulated depreciation of $1 and $1, respectively

6

 

 

6

 

Other

77

 

 

125

 

Total

$

799

 

 

$

941

 

 

MidAmerican Energy has established a trust for the investment of funds for decommissioning the Quad Cities Station. The debt and equity securities in the trust are reported at fair value. Funds are invested in the trust in accordance with applicable federal and state investment guidelines and are restricted for use as reimbursement for costs of decommissioning the Quad Cities Station, which is currently licensed for operation until December 2032. As of December 31, 2018 and 2017, the fair value of the trust's funds was invested as follows: 51% and 56%, respectively, in domestic common equity securities, 37% and 34%, respectively, in United States government securities, 9% and 7%, respectively, in domestic corporate debt securities and 3% and 3%, respectively, in other securities.

 

Rabbi trusts primarily hold corporate-owned life insurance on certain current and former key executives and directors. The Rabbi trusts were established to hold investments used to fund the obligations of various nonqualified executive and director compensation plans and to pay the costs of the trusts. The amount represents the cash surrender value of all of the policies included in the Rabbi trusts, net of amounts borrowed against the cash surrender value. Changes in the cash surrender value of the policies are reflected in other income deductions on the Statements of Income.

 

 

(6) Short-Term Debt and Credit Facilities

 

Interim financing of working capital needs and the construction program is obtained from unaffiliated parties through the sale of commercial paper or short-term borrowing from banks. MidAmerican Energy has a $900 million unsecured credit facility expiring June 2021 with a one-year extension option subject to lender consent. The credit facility, which supports MidAmerican Energy's commercial paper program and its variable-rate tax-exempt bond obligations and provides for the issuance of letters of credit, has a variable interest rate based on the Eurodollar rate or a base rate, at MidAmerican Energy's option, plus a spread that varies based on MidAmerican Energy's credit ratings for senior unsecured long-term debt securities. In addition, MidAmerican Energy has a $5 million unsecured credit facility, which expires in June 2019 and has a variable interest rate based on the Eurodollar rate plus a spread. As of December 31, 2018, MidAmerican Energy had a $400 million unsecured credit facility expiring November 2019, which was terminated in January 2019. As of December 31, 2018, the weighted average interest rate on commercial paper borrowings outstanding was 2.49%. The $900 million credit facility requires that MidAmerican Energy's ratio of consolidated debt, including current maturities, to total capitalization not exceed 0.65 to 1.0 as of the last day of any quarter. As of December 31, 2018, MidAmerican Energy was in compliance with the covenants of its credit facilities. MidAmerican Energy has authority from the FERC to issue commercial paper and bank notes aggregating $1.3 billion through July 31, 2020.

 



The following table summarizes MidAmerican Energy's availability under its two unsecured revolving credit facilities as of December 31 (in millions):

 

2018

 

2017

 

 

 

 

Credit facilities

$

1,305

 

 

$

905

 

Less:

 

 

 

Short-term debt outstanding

(240

)

 

 

Variable-rate tax-exempt bond support

(370

)

 

(370

)

Net credit facilities

$

695

 

 

$

535

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(7) Long-Term Debt

 

MidAmerican Energy's long-term debt consists of the following, including amounts maturing within one year and unamortized premiums and discounts, as of December 31 (dollars in millions):

 

Par Value

 

2018

 

2017

 

 

 

 

 

 

First mortgage bonds:

 

 

 

 

 

2.40%, due 2019

$

500

 

 

$

500

 

 

$

500

 

3.70%, due 2023

250

 

 

249

 

 

249

 

3.50%, due 2024

500

 

 

503

 

 

504

 

3.10%, due 2027

375

 

 

375

 

 

375

 

4.80%, due 2043

350

 

 

349

 

 

349

 

4.40%, due 2044

400

 

 

398

 

 

398

 

4.25%, due 2046

450

 

 

449

 

 

449

 

3.95%, due 2047

475

 

 

474

 

 

474

 

3.65%, due 2048

700

 

 

694

 

 

 

Notes:

 

 

 

 

 

5.3% Series, due 2018

 

 

 

 

350

 

6.75% Series, due 2031

400

 

 

398

 

 

398

 

5.75% Series, due 2035

300

 

 

300

 

 

300

 

5.8% Series, due 2036

350

 

 

350

 

 

350

 

Transmission upgrade obligation, 4.45% and 3.42% due through 2035 and 2036, respectively

6

 

 

5

 

 

6

 

Variable-rate tax-exempt bond obligation series: (weighted average interest rate- 2018-1.74%, 2017-1.91%):

 

 

 

 

 

Due 2023, issued in 1993

7

 

 

7

 

 

7

 

Due 2023, issued in 2008

57

 

 

57

 

 

57

 

Due 2024

35

 

 

35

 

 

35

 

Due 2025

13

 

 

13

 

 

13

 

Due 2036

33

 

 

33

 

 

33

 

Due 2038

45

 

 

45

 

 

45

 

Due 2046

30

 

 

30

 

 

30

 

Due 2047

150

 

 

150

 

 

150

 

Total

$

5,428

 

 

$

5,414

 

 

$

5,072

 

 

 



 

The annual repayments of MidAmerican Energy's long-term debt for the years beginning January 1, 2019, and thereafter, excluding unamortized premiums and discounts, are as follows (in millions):

2019

 

$

500

 

2020

 

 

2021

 

 

2022

 

 

2023

 

315

 

2024 and thereafter

 

4,611

 

 

In January 2019, MidAmerican Energy issued $600 million of its 3.65% First Mortgage Bonds due April 2029 and $900 million of its 4.25% First Mortgage Bonds due July 2049. In February 2019, MidAmerican Energy redeemed $500 million of its 2.40% First Mortgage Bonds due in March 2019 at a redemption price of 100% of the principal amount plus accrued interest.

 

Pursuant to MidAmerican Energy's mortgage dated September 9, 2013, MidAmerican Energy's first mortgage bonds, currently and from time to time outstanding, are secured by a first mortgage lien on substantially all of its electric generating, transmission and distribution property within the State of Iowa, subject to certain exceptions and permitted encumbrances. As of December 31, 2018, MidAmerican Energy's eligible property subject to the lien of the mortgage totaled approximately $18 billion based on original cost. Additionally, MidAmerican Energy's senior notes outstanding are equally and ratably secured with the first mortgage bonds as required by the indentures under which the senior notes were issued.

 

MidAmerican Energy's variable-rate tax-exempt bond obligations bear interest at rates that are periodically established through remarketing of the bonds in the short-term tax-exempt market. MidAmerican Energy, at its option, may change the mode of interest calculation for these bonds by selecting from among several floating or fixed rate alternatives. The interest rates shown in the table above are the weighted average interest rates as of December 31, 2018 and 2017. MidAmerican Energy maintains revolving credit facility agreements to provide liquidity for holders of these issues. Additionally, MidAmerican Energy's obligations associated with the $30 million and $150 million variable rate, tax-exempt bond obligations due 2046 and 2047, respectively, are secured by an equal amount of first mortgage bonds pursuant to MidAmerican Energy's mortgage dated September 9, 2013, as supplemented and amended. Proceeds of the $150 million of variable-rate, tax-exempt Solid Waste Facilities Revenue Bonds due December 2047 are restricted for the purpose of constructing solid waste facilities. As of December 31, 2018, $56 million of the restricted proceeds remain and are reflected in other property and investments on the Balance Sheet.

 

As of December 31, 2018, MidAmerican Energy was in compliance with all of its applicable long-term debt covenants.

 

In March 1999, MidAmerican Energy committed to the IUB to use commercially reasonable efforts to maintain an investment grade rating on its long-term debt and to maintain its common equity level above 42% of total capitalization unless circumstances beyond its control result in the common equity level decreasing to below 39% of total capitalization. MidAmerican Energy must seek the approval from the IUB of a reasonable utility capital structure if MidAmerican Energy's common equity level decreases below 42% of total capitalization, unless the decrease is beyond the control of MidAmerican Energy. MidAmerican Energy is also required to seek the approval of the IUB if MidAmerican Energy's equity level decreases to below 39%, even if the decrease is due to circumstances beyond the control of MidAmerican Energy. As of December 31, 2018, MidAmerican Energy's common equity ratio was 53% computed on a basis consistent with its commitment. As a result of its regulatory commitment to maintain its common equity level above certain thresholds, MidAmerican Energy could dividend $2.5 billion as of December 31, 2018, without falling below 42%.

 

 

 

 

 

 

 

 

(8) Income Taxes

 

Tax Cuts and Jobs Act

 

The 2017 Tax Reform impacts many areas of income tax law. The most material items include the reduction of the federal corporate tax rate from 35% to 21% effective January 1, 2018 and limitations on bonus depreciation for utility property. GAAP requires the effect on deferred tax assets and liabilities of a change in tax rates be recognized in the period the tax rate change was enacted. As a result of the 2017 Tax Reform, MidAmerican Energy reduced deferred income tax liabilities $1,824 million. As it is probable the change in deferred taxes will be passed back to customers through regulatory mechanisms, MidAmerican Energy increased net regulatory liabilities by $1,845 million.

 

In December 2017, the Securities and Exchange Commission issued Staff Accounting Bulletin ("SAB") 118 to assist in the implementation process of the 2017 Tax Reform by allowing for calculations to be classified as provisional and subject to remeasurement. There are three different classifications for the accounting: (1) completed, (2) not complete but reasonably estimable or (3) not complete and amounts are not reasonably estimable. On December 31, 2017, MidAmerican Energy recorded the impacts of 2017 Tax Reform and believed all the impacts to be complete with the exception of interpretations of the bonus depreciation rules. MidAmerican Energy determined the amounts recorded and the interpretations relating to this item to be provisional and subject to remeasurement during the measurement period upon obtaining the necessary additional information to complete the accounting. MidAmerican Energy believed its interpretations for bonus depreciation to be reasonable, however, clarifying guidance was needed. During 2018, MidAmerican Energy recorded a current tax benefit of $27 million and a deferred tax expense of $28 million following clarifying bonus depreciation guidance. As a result of 2017 Tax Reform, MidAmerican Energy reduced the associated deferred income tax liabilities $12 million and increased regulatory liabilities by the same amount.

 

MidAmerican Energy's income tax benefit consists of the following for the years ended December 31 (in millions):

 

2018

 

2017

 

Current:

 

 

 

 

Federal

$

(284

)

 

$

(483

)

 

State

(11

)

 

(26

)

 

 

(295

)

 

(509

)

 

Deferred:

 

 

 

 

Federal

50

 

 

328

 

 

State

(8

)

 

(2

)

 

 

42

 

 

326

 

 

 

 

 

 

 

Investment tax credits

(1

)

 

(1

)

 

Total

$

(254

)

 

$

(184

)

 

 

Iowa Senate File 2417

 

In May 2018, Iowa Senate File 2417 was signed into law, which, among other items, reduces the state of Iowa corporate tax rate from 12% to 9.8% and eliminates corporate federal deductibility, both for tax years starting in 2021. GAAP requires the effect on deferred tax assets and liabilities of a change in tax rates be recognized in the period the tax rate change was enacted. As a result of Iowa Senate File 2417, MidAmerican Energy reduced net deferred income tax liabilities $54 million and decreased deferred income tax benefit by $2 million. As it is probable the change in deferred taxes for MidAmerican Energy will be passed back to customers through regulatory mechanisms, MidAmerican Energy increased net regulatory liabilities by $56 million.

 

 

A reconciliation of the federal statutory income tax rate to MidAmerican Energy's effective income tax rate applicable to income before income tax benefit from continuing operations is as follows for the years ended December 31:

 

2018

 

2017

 

 

 

 

 

 

Federal statutory income tax rate

21

%

 

35

%

 

Income tax credits

(73

)

 

(68

)

 

State income tax, net of federal income tax benefit

(4

)

 

(4

)

 

Effects of ratemaking

(5

)

 

(7

)

 

2017 Tax Reform

1

 

 

2

 

 

Other, net

 

 

(1

)

 

Effective income tax rate

(60

)%

 

(43

)%

 

 

Income tax credits relate primarily to production tax credits earned by MidAmerican Energy's wind-powered generating facilities. Federal renewable electricity production tax credits are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in-service.

 

MidAmerican Energy's net deferred income tax liability consists of the following as of December 31 (in millions):

 

2018

 

2017

Deferred income tax assets:

 

 

 

 

 

 

 

 

 

 

 

Depreciable property

$

20

 

 

$

23

 

Regulatory liabilities

 

219

 

 

 

260

 

Employee benefits

 

47

 

 

 

45

 

Asset retirement obligations

45

 

 

38

 

State NOL

56

 

 

50

 

Other

47

 

 

35

 

Total deferred income tax assets

434

 

 

451

 

 

 

 

 

Deferred income tax liabilities:

 

 

 

Depreciable property

(2,655

)

 

(2,575

)

Regulatory assets

(71

)

 

(55

)

Other

(35

)

 

(65

)

Total deferred income tax liabilities

(2,761

)

 

(2,695

)

 

 

 

 

Net deferred income tax liability

$

(2,327

)

 

$

(2,244

)

 

As of December 31, 2018, MidAmerican Energy has available $44 million of state tax carryforwards, principally related to $655 million of net operating losses, that expire at various intervals between 2019 and 2037.

 

 

The United States Internal Revenue Service has closed its examination of MidAmerican Energy's income tax returns through December 31, 2011. The statute of limitations for MidAmerican Energy's state income tax returns have expired through December 31, 2009, with the exception of Iowa and Illinois, for which the statute of limitations have expired through December 31, 2014, except for the impact of any federal audit adjustments. The statute of limitations expiring for state filings may not preclude the state from adjusting the state net operating loss carryforward utilized in a year for which the statute of limitations is not closed.

 

A reconciliation of the beginning and ending balances of MidAmerican Energy's net unrecognized tax benefits is as follows for the years ended December 31 (in millions):

 

2018

 

2017

 

 

 

 

Beginning balance

$

12

 

 

$

10

 

Additions based on tax positions related to the current year

4

 

 

1

 

Additions for tax positions of prior years

47

 

 

23

 

Reductions based on tax positions related to the current year

(4

)

 

(4

)

Reductions for tax positions of prior years

(48

)

 

(19

)

Interest and penalties

(1

)

 

1

 

Ending balance

$

10

 

 

$

12

 

 

As of December 31, 2018, MidAmerican Energy had unrecognized tax benefits totaling $29 million that, if recognized, would have an impact on the effective tax rate. The remaining unrecognized tax benefits relate to tax positions for which ultimate deductibility is highly certain but for which there is uncertainty as to the timing of such deductibility. Recognition of these tax benefits, other than applicable interest and penalties, would not affect MidAmerican Energy's effective income tax rate.

 

 

(9) Employee Benefit Plans

 

Defined Benefit Plan

 

MidAmerican Energy sponsors a noncontributory defined benefit pension plan covering a majority of all employees of BHE and its domestic energy subsidiaries other than PacifiCorp and NV Energy, Inc. Benefit obligations under the plan are based on a cash balance arrangement for salaried employees and most union employees and final average pay formulas for other union employees. MidAmerican Energy also maintains noncontributory, nonqualified defined benefit supplemental executive retirement plans ("SERP") for certain active and retired participants. In 2018, the defined benefit pension plan recorded a settlement gain of $1 million for previously unrecognized gains as a result of excess lump sum distributions over the defined threshold for the year ended December 31, 2018.

 

MidAmerican Energy also sponsors certain postretirement healthcare and life insurance benefits covering substantially all retired employees of BHE and its domestic energy subsidiaries other than PacifiCorp and NV Energy, Inc. Under the plans, a majority of all employees of the participating companies may become eligible for these benefits if they reach retirement age. New employees are not eligible for benefits under the plans. MidAmerican Energy has been allowed to recover accrued pension and other postretirement benefit costs in its electric and gas service rates.

 

Net Periodic Benefit Cost

 

For purposes of calculating the expected return on pension plan assets, a market-related value is used. The market-related value of plan assets is calculated by spreading the difference between expected and actual investment returns on equity investments over a five-year period beginning after the first year in which they occur.

 


MidAmerican Energy bills to and is reimbursed currently for affiliates' share of the net periodic benefit costs from all plans in which such affiliates participate. In 2018 and 2017, MidAmerican Energy's share of the pension net periodic benefit (credit) cost was $(9) million and $(6) million, respectively. MidAmerican Energy's share of the other postretirement net periodic benefit (credit) cost in 2018 and 2017 totaled $(2) million and $(1) million, respectively.

 

Net periodic benefit cost for the plans of MidAmerican Energy and the aforementioned affiliates included the following components for the years ended December 31 (in millions):

 

Pension

 

Other Postretirement

 

2018

 

2017

 

 

2018

 

2017

 

 

 

 

 

 

 

 

 

 

 

Service cost

$

9

 

 

$

9

 

 

 

$

5

 

 

$

5

 

 

Interest cost

28

 

 

31

 

 

 

8

 

 

9

 

 

Expected return on plan assets

(44

)

 

(44

)

 

 

(13

)

 

(14

)

 

Settlement

(1

)

 

 

 

 

 

 

 

 

Net amortization

2

 

 

2

 

 

 

(4

)

 

(4

)

 

Net periodic benefit (credit) cost

$

(6

)

 

$

(2)

 

 

 

$

(4

)

 

$

(4

)

 

 

Funded Status

 

The following table is a reconciliation of the fair value of plan assets for the years ended December 31 (in millions):

 

Pension

 

Other Postretirement

 

2018

 

2017

 

2018

 

2017

 

 

 

 

 

 

 

 

Plan assets at fair value, beginning of year

$

745

 

 

$

684

 

 

$

277

 

 

$

252

 

Employer contributions

7

 

 

7

 

 

1

 

 

1

 

Participant contributions

 

 

 

 

1

 

 

1

 

Actual return on plan assets

(39

)

 

114

 

 

(17

)

 

36

 

Settlement

(37

)

 

 

 

 

 

 

Benefits paid

(32

)

 

(60

)

 

(15

)

 

(13

)

Plan assets at fair value, end of year

$

644

 

 

$

745

 

 

$

247

 

 

$

277

 

 

 

 

 


 

 

 

The following table is a reconciliation of the benefit obligations for the years ended December 31 (in millions):

 

Pension

 

Other Postretirement

 

2018

 

2017

 

2018

 

2017

 

 

 

 

 

 

 

 

Benefit obligation, beginning of year

$

799

 

 

$

773

 

 

$

246

 

 

$

233

 

Service cost

9

 

 

9

 

 

5

 

 

5

 

Interest cost

28

 

 

31

 

 

8

 

 

9

 

Participant contributions

 

 

 

 

1

 

 

1

 

Actuarial (gain) loss

(33

)

 

46

 

 

(3

)

 

11

 

Plan amendments

2

 

 

 

 

 

 

 

Settlement

(37

)

 

 

 

 

 

 

Benefits paid

(32

)

 

(60

)

 

(15

)

 

(13

)

Benefit obligation, end of year

$

736

 

 

$

799

 

 

$

242

 

 

$

246

 

Accumulated benefit obligation, end of year

$

733

 

 

$

790

 

 

 

 

 

 

The funded status of the plans and the amounts recognized on the Balance Sheets as of December 31 are as follows (in millions):

 

Pension

 

Other Postretirement

 

2018

 

2017

 

2018

 

2017

 

 

 

 

 

 

 

 

Plan assets at fair value, end of year

$

644

 

 

$

745

 

 

$

247

 

 

$

277

 

Less - Benefit obligation, end of year

736

 

 

799

 

 

242

 

 

246

 

Funded status

$

(92

)

 

$

(54

)

 

$

5

 

 

$

31

 

 

 

 

 

 

 

 

 

Amounts recognized on the Balance Sheets:

 

 

 

 

 

 

 

Other assets

$

17

 

 

$

66

 

 

$

5

 

 

$

31

 

Other current liabilities

(7

)

 

(8

)

 

 

 

 

Other liabilities

(102

)

 

(112

)

 

 

 

 

Amounts recognized

$

(92

)

 

$

(54

)

 

$

5

 

 

$

31

 

 

The SERP has no plan assets; however, MidAmerican Energy and BHE have Rabbi trusts that hold corporate-owned life insurance and other investments to provide funding for the future cash requirements of the SERP. The cash surrender value of all of the policies included in MidAmerican Energy's Rabbi trusts, net of amounts borrowed against the cash surrender value, plus the fair market value of other Rabbi trust investments, was $116 million and $118 million as of December 31, 2018 and 2017. These assets are not included in the plan assets in the above table, but are reflected in other property and investments on the Balance Sheets. The accumulated benefit obligation and projected benefit obligation for the SERP was $109 million and $109 million, respectively, for 2018 and $118 million and $120 million, respectively, for 2017.

 

 

 

 

 

 

Unrecognized Amounts

 

The portion of the funded status of the plans not yet recognized in net periodic benefit cost as of December 31 is as follows (in millions):

 

Pension

 

Other Postretirement

 

2018

 

2017

 

2018

 

2017

 

 

 

 

 

 

 

 

Net loss (gain)

$

40

 

 

$

(11

)

 

$

48

 

 

$

23

 

Prior service cost (credit)

1

 

 

1

 

 

(20

)

 

(25

)

Total

$

41

 

 

$

(10

)

 

$

28

 

 

$

(2

)

 

MidAmerican Energy sponsors pension and other postretirement benefit plans on behalf of certain of its affiliates in addition to itself, and therefore, the portion of the funded status of the respective plans that has not yet been recognized in net periodic benefit cost is attributable to multiple entities. Additionally, substantially all of MidAmerican Energy's portion of such amounts is either refundable to or recoverable from its customers and is reflected as regulatory liabilities and regulatory assets.

 

A reconciliation of the amounts not yet recognized as components of net periodic benefit cost for the years ended December 31, 2018 and 2017 is as follows (in millions):

 

Regulatory Asset

 

Regulatory Liability

 

Receivables

(Payables)

with Affiliates

 

Total

Pension

 

 

 

 

 

 

 

Balance, December 31, 2016

$

22

 

 

$

(12

)

 

$

6

 

 

$

16

 

Net loss (gain) arising during the year

4

 

 

(29

)

 

1

 

 

(24

)

Net amortization

(2

)

 

 

 

 

 

(2

)

Total

2

 

 

(29

)

 

1

 

 

(26

)

Balance, December 31, 2017

24

 

 

(41

)

 

7

 

 

(10

)

Net loss arising during the year

2

 

 

41

 

 

9

 

 

52

 

Net amortization

(2

)

 

 

 

 

 

(2

)

Settlement

1

 

 

 

 

 

 

1

 

Total

1

 

 

41

 

 

9

 

 

51

 

Balance, December 31, 2018

$

25

 

 

$

 

 

$

16

 

 

$

41

 

 

 

 

 

 

 

 

Regulatory Asset

 

Receivables

(Payables)

with Affiliates

 

Total

Other Postretirement

 

 

 

 

 

Balance, December 31, 2016

$

18

 

 

$

(13

)

 

$

5

 

Net gain arising during the year

(7

)

 

(4

)

 

(11

)

Net amortization

3

 

 

1

 

 

4

 

Total

(4

)

 

(3

)

 

(7

)

Balance, December 31, 2017

14

 

 

(16

)

 

(2

)

Net loss arising during the year

20

 

 

6

 

 

26

 

Net amortization

3

 

 

1

 

 

4

 

Total

23

 

 

7

 

 

30

 

Balance, December 31, 2018

$

37

 

 

$

(9

)

 

$

28

 

 

Actuarial losses for 2018 impacting the December 31, 2018 funded status for the pension and other postretirement plans are due to lower than assumed actual return on plan assets, offset by an increase in the discount rate assumptions from that assumed at December 31, 2017.

 

Plan Assumptions

 

Assumptions used to determine benefit obligations and net periodic benefit cost were as follows:

 

Pension

Other Postretirement

 

2018

 

2017

 

 

2018

 

2017

 

Benefit obligations as of December 31:

 

 

 

 

 

 

 

 

 

Discount rate

4.25

%

 

3.60

%

 

 

4.15

%

 

3.50

%

 

Rate of compensation increase

2.75

%

 

2.75

%

 

 

N/A

 

N/A

 

Interest crediting rates for cash balance plan

 

 

 

 

 

 

 

 

 

2016

N/A

 

N/A

 

 

N/A

 

N/A

 

2017

N/A

 

1.44

%

 

 

N/A

 

N/A

 

2018

2.26

%

 

2.26

%

 

 

N/A

 

N/A

 

2019

3.40

%

 

2.26

%

 

 

N/A

 

N/A

 

2020

3.40

%

 

1.60

%

 

 

N/A

 

N/A

 

2021 and beyond

3.40

%

 

1.60

%

 

 

N/A

 

N/A

 

 

 

 

 

 

 

 

 

 

 

Net periodic benefit cost for the years ended December 31:

 

 

 

 

 

 

 

 

 

Discount rate

3.60

%

 

4.10

%

 

 

3.50

%

 

3.90

%

 

Expected return on plan assets(1)

6.50

%

 

6.75

%

 

 

6.25

%

 

6.50

%

 

Rate of compensation increase

2.75

%

 

2.75

%

 

 

N/A

 

N/A

 

Interest crediting rates for cash balance plan

2.26

%

 

1.44

%

 

 

N/A

 

N/A

 

  1. Amounts reflected are pre-tax values. Assumed after-tax returns for a taxable, non-union other postretirement plan were 4.13% for 2018, and 4.81% for 2017.


In establishing its assumption as to the expected return on plan assets, MidAmerican Energy utilizes the asset allocation and return assumptions for each asset class based on historical performance and forward-looking views of the financial markets.

 

2018

 

2017

Assumed healthcare cost trend rates as of December 31:

 

 

 

Healthcare cost trend rate assumed for next year

6.80

%

 

7.10

%

Rate that the cost trend rate gradually declines to

5.00

%

 

5.00

%

Year that the rate reaches the rate it is assumed to remain at

2025

 

2025

 

Contributions and Benefit Payments

 

Employer contributions to the pension and other postretirement benefit plans are expected to be $7 million and $1 million, respectively, during 2019. Funding to MidAmerican Energy's pension benefit plan trust is based upon the actuarially determined costs of the plan and the requirements of the Internal Revenue Code, the Employee Retirement Income Security Act of 1974 and the Pension Protection Act of 2006, as amended. MidAmerican Energy considers contributing additional amounts from time to time in order to achieve certain funding levels specified under the Pension Protection Act of 2006, as amended. MidAmerican Energy's funding policy for its other postretirement benefit plan is to generally contribute amounts consistent with its rate regulatory arrangements.

 

Net periodic benefit costs assigned to MidAmerican Energy affiliates are reimbursed currently in accordance with its intercompany administrative services agreement. The expected benefit payments to participants in MidAmerican Energy's pension and other postretirement benefit plans for 2019 through 2023 and for the five years thereafter are summarized below (in millions):

 

Projected Benefit Payments

 

Pension

 

Other Postretirement

 

 

 

 

2019

$

61

 

 

$

19

 

2020

62

 

 

21

 

2021

61

 

 

22

 

2022

60

 

 

22

 

2023

58

 

 

22

 

2024-2028

262

 

 

102

 

 

Plan Assets

 

Investment Policy and Asset Allocations

 

MidAmerican Energy's investment policy for its pension and other postretirement benefit plans is to balance risk and return through a diversified portfolio of debt securities, equity securities and other alternative investments. Maturities for debt securities are managed to targets consistent with prudent risk tolerances. The plans retain outside investment advisors to manage plan investments within the parameters outlined by the MidAmerican Energy Pension and Employee Benefits Plans Administrative Committee. The investment portfolio is managed in line with the investment policy with sufficient liquidity to meet near-term benefit payments.

 

 

 

The target allocations (percentage of plan assets) for MidAmerican Energy's pension and other postretirement benefit plan assets are as follows as of December 31, 2018:

 

Pension

 

Other

Postretirement

 

%

 

%

Debt securities(1)

20-50

 

25-45

Equity securities(1)

60-80

 

45-80

Real estate funds

2-8

 

Other

0-3

 

0-5

 

  1. For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Fair Value Measurements

 

The following table presents the fair value of plan assets, by major category, for MidAmerican Energy's defined benefit pension plan (in millions):

 

Input Levels for Fair Value Measurements(1)

 

 

 

Level 1

 

Level 2

 

Level 3

 

Total

As of December 31, 2018:

 

 

 

 

 

 

 

Cash equivalents

$

 

 

$

20

 

 

$

 

 

$

20

 

Debt securities:

 

 

 

 

 

 

 

United States government obligations

6

 

 

 

 

 

 

6

 

Corporate obligations

 

 

63

 

 

 

 

63

 

Municipal obligations

 

 

6

 

 

 

 

6

 

Agency, asset and mortgage-backed obligations

 

 

37

 

 

 

 

37

 

Equity securities:

 

 

 

 

 

 

 

United States companies

111

 

 

 

 

 

 

111

 

International companies

35

 

 

 

 

 

 

35

 

Investment funds(2)

65

 

 

 

 

 

 

65

 

Total assets in the hierarchy

$

217

 

 

$

126

 

 

$

 

 

343

 

Investment funds(2) measured at net asset value

 

 

 

 

 

 

260

 

Real estate funds measured at net asset value

 

 

 

 

 

 

41

 

Total assets measured at fair value

 

 

 

 

 

 

$

644

 

 

 

 

 

 

 

 

 

As of December 31, 2017:

 

 

 

 

 

 

 

Cash equivalents

$

 

 

$

17

 

 

$

 

 

$

17

 

Debt securities:

 

 

 

 

 

 

 

United States government obligations

21

 

 

 

 

 

 

21

 

Corporate obligations

 

 

59

 

 

 

 

59

 

Municipal obligations

 

 

7

 

 

 

 

7

 

Agency, asset and mortgage-backed obligations

 

 

33

 

 

 

 

33

 

Equity securities:

 

 

 

 

 

 

 

United States companies

137

 

 

 

 

 

 

137

 

International companies

44

 

 

 

 

 

 

44

 

Investment funds(2)

74

 

 

 

 

 

 

74

 

Total assets in the hierarchy

$

276

 

 

$

116

 

 

$

 

 

392

 

Investment funds(2) measured at net asset value

 

 

 

 

 

 

315

 

Real estate funds measured at net asset value

 

 

 

 

 

 

38

 

Total assets measured at fair value

 

 

 

 

 

 

$

745

 

(1) Refer to Note 11 for additional discussion regarding the three levels of the fair value hierarchy.

  1. Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 65% and 35%, respectively, for 2018 and 69% and 31%, respectively, for 2017. Additionally, these funds are invested in United States and international securities of approximately 74% and 26%, respectively, for 2018 and 72% and 28%, respectively, for 2017.

 

The following table presents the fair value of plan assets, by major category, for MidAmerican Energy's defined benefit other postretirement plans (in millions):

 

Input Levels for Fair Value Measurements(1)

 

 

 

Level 1

 

Level 2

 

Level 3

 

Total

As of December 31, 2018:

 

 

 

 

 

 

 

Cash equivalents

$

5

 

 

$

 

 

$

 

 

$

5

 

Debt securities:

 

 

 

 

 

 

 

United States government obligations

6

 

 

 

 

 

 

6

 

Corporate obligations

 

 

12

 

 

 

 

12

 

Municipal obligations

 

 

43

 

 

 

 

43

 

Agency, asset and mortgage-backed obligations

 

 

12

 

 

 

 

12

 

Equity securities:

 

 

 

 

 

 

 

United States companies

73

 

 

 

 

 

 

73

 

Investment funds(2)

96

 

 

 

 

 

 

96

 

Total assets measured at fair value

$

180

 

 

$

67

 

 

$

 

 

$

247

 

 

 

 

 

 

 

 

 

As of December 31, 2017:

 

 

 

 

 

 

 

Cash equivalents

$

6

 

 

$

 

 

$

 

 

$

6

 

Debt securities:

 

 

 

 

 

 

 

United States government obligations

5

 

 

 

 

 

 

5

 

Corporate obligations

 

 

14

 

 

 

 

14

 

Municipal obligations

 

 

44

 

 

 

 

44

 

Agency, asset and mortgage-backed obligations

 

 

12

 

 

 

 

12

 

Equity securities:

 

 

 

 

 

 

 

United States companies

84

 

 

 

 

 

 

84

 

Investment funds(2)

112

 

 

 

 

 

 

112

 

Total assets measured at fair value

$

207

 

 

$

70

 

 

$

 

 

$

277

 

 

  1. Refer to Note 11 for additional discussion regarding the three levels of the fair value hierarchy.

  2. Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately 78% and 22%, respectively, for 2018 and 81% and 19%, respectively, for 2017. Additionally, these funds are invested in United States and international securities of approximately 41% and 59%, respectively, for 2018 and 42% and 58%, respectively, for 2017.

 

For level 1 investments, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. For level 2 investments, the fair value is determined using pricing models based on observable market inputs. Shares of mutual funds not registered under the Securities Act of 1933, private equity limited partnership interests, common and commingled trust funds and investment entities are reported at fair value based on the net asset value per unit, which is used for expedience purposes. A fund's net asset value is based on the fair value of the underlying assets held by the fund less its liabilities.

Defined Contribution Plan

 

MidAmerican Energy sponsors a defined contribution plan ("401(k) plan") covering substantially all employees. MidAmerican Energy's matching contributions are based on each participant's level of contribution, and certain participants receive contributions based on eligible pre-tax annual compensation. Contributions cannot exceed the maximum allowable for tax purposes. Certain participants now receive enhanced benefits in the 401(k) plan and no longer accrue benefits in the noncontributory defined benefit pension plans. MidAmerican Energy's contributions to the plan were $22 million and $20 million for the years ended December 31, 2018 and 2017, respectively.

 

 

(10) Asset Retirement Obligations

 

MidAmerican Energy estimates its ARO liabilities based upon detailed engineering calculations of the amount and timing of the future cash spending for a third party to perform the required work. Spending estimates are escalated for inflation and then discounted at a credit-adjusted, risk-free rate. Changes in estimates could occur for a number of reasons, including changes in laws and regulations, plan revisions, inflation and changes in the amount and timing of the expected work.

 

MidAmerican Energy does not recognize liabilities for AROs for which the fair value cannot be reasonably estimated. Due to the indeterminate removal date, the fair value of the associated liabilities on certain generation, transmission, distribution and other assets cannot currently be estimated, and no amounts are recognized on the Financial Statements other than those included in the cost of removal component of accumulated depreciation established via approved depreciation rates in accordance with accepted regulatory practices. These accruals totaled $708 million and $688 million as of December 31, 2018 and 2017, respectively.

 

The following table presents MidAmerican Energy's ARO liabilities by asset type as of December 31 (in millions):

 

2018

 

2017

 

 

 

 

Quad Cities Station

$

345

 

 

$

342

 

Fossil-fueled generating facilities

93

 

 

113

 

Wind-powered generating facilities

123

 

 

103

 

Other

1

 

 

1

 

Total asset retirement obligations

$

562

 

 

$

559

 

 

 

 

 

Quad Cities Station nuclear decommissioning trust funds(1)

$

504

 

 

$

515

 

 

(1) Refer to Note 5 for a discussion of the Quad Cities Station nuclear decommissioning trust funds.

 

 

 

 

 

 



The following table reconciles the beginning and ending balances of MidAmerican Energy's ARO liabilities for the years ended December 31 (in millions):

 

2018

 

2017

 

 

 

 

Beginning balance

$

559

 

 

$

567

 

Change in estimated costs

(10

)

 

(14

)

Additions

17

 

 

8

 

Retirements

(28

)

 

(26

)

Accretion

24

 

 

24

 

Ending balance

$

562

 

 

$

559

 

 

 

 

 

Reflected as:

 

 

 

Other current liabilities

$

10

 

 

$

31

 

Asset retirement obligations

552

 

 

528

 

 

$

562

 

 

$

559

 

 

The changes in estimated costs relate primarily to the Quad Cities Station due to a change in the inflation rate and, for 2017, a new decommissioning study conducted by the operator of Quad Cities Station that changed the estimated amount and timing of cash flows.

 

In January 2018, MidAmerican Energy completed groundwater testing at its coal combustion residuals ("CCR") surface impoundments. Based on this information, MidAmerican Energy discontinued sending CCR to surface impoundments effective April 2018 and will remove all CCR material located below the water table in such facilities, the latter of which is a more extensive closure activity than previously assumed. The incremental cost and timing of such actions is not currently reasonably determinable, but an evaluation of such estimates is expected to be completed in the first quarter of 2019, with any necessary adjustments to the related asset retirement obligations recognized at that time.

 

 

(11) Fair Value Measurements

 

The carrying value of MidAmerican Energy's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. MidAmerican Energy has various financial assets and liabilities that are measured at fair value on the Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

 

  • Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that MidAmerican Energy has the ability to access at the measurement date.

  • Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).

  • Level 3 - Unobservable inputs reflect MidAmerican Energy's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. MidAmerican Energy develops these inputs based on the best information available, including its own data.

The following table presents MidAmerican Energy's assets and liabilities on the Balance Sheets and measured at fair value on a recurring basis (in millions):

 

 

Input Levels for Fair Value Measurements

 

 

 

 

 

 

Level 1

 

Level 2

 

Level 3

 

Other(1)

 

Total

As of December 31, 2018

 

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

 

Commodity derivatives

 

$

 

 

$

4

 

 

$

2

 

 

$

(3

)

 

$

3

 

Money market mutual funds(2)

 

2

 

 

 

 

 

 

 

 

2

 

Debt securities:

 

 

 

 

 

 

 

 

 

 

United States government obligations

 

187

 

 

 

 

 

 

 

 

187

 

International government obligations

 

 

 

4

 

 

 

 

 

 

4

 

Corporate obligations

 

 

 

46

 

 

 

 

 

 

46

 

Municipal obligations

 

 

 

2

 

 

 

 

 

 

2

 

Agency, asset and mortgage-backed obligations

 

 

 

1

 

 

 

 

 

 

1

 

Equity securities:

 

 

 

 

 

 

 

 

 

 

United States companies

 

256

 

 

 

 

 

 

 

 

256

 

International companies

 

6

 

 

 

 

 

 

 

 

6

 

Investment funds

 

10

 

 

 

 

 

 

 

 

10

 

 

 

$

461

 

 

$

57

 

 

$

2

 

 

$

(3

)

 

$

517

 

Liabilities:

 

 

 

 

 

 

 

 

 

 

Commodity derivatives

 

$

 

 

$

(4

)

 

$

(2

)

 

$

3

 

 

$

(3

)

Interest rate derivatives(3)

 

 

 

(19

)

 

 

 

 

 

(19

)

 

 

$

 

 

$

(23

)

 

$

(2

)

 

$

3

 

 

$

(22

)

As of December 31, 2017

 

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

 

Commodity derivatives

 

$

 

 

$

3

 

 

$

4

 

 

$

(2

)

 

$

5

 

Money market mutual funds(2)

 

133

 

 

 

 

 

 

 

 

133

 

Debt securities:

 

 

 

 

 

 

 

 

 

 

United States government obligations

 

176

 

 

 

 

 

 

 

 

176

 

International government obligations

 

 

 

5

 

 

 

 

 

 

5

 

Corporate obligations

 

 

 

36

 

 

 

 

 

 

36

 

Municipal obligations

 

 

 

2

 

 

 

 

 

 

2

 

Equity securities:

 

 

 

 

 

 

 

 

 

 

United States companies

 

288

 

 

 

 

 

 

 

 

288

 

International companies

 

7

 

 

 

 

 

 

 

 

7

 

Investment funds

 

15

 

 

 

 

 

 

 

 

15

 

 

 

$

619

 

 

$

46

 

 

$

4

 

 

$

(2

)

 

$

667

 

Liabilities - commodity derivatives

 

$

 

 

$

(9

)

 

$

(1

)

 

$

2

 

 

$

(8

)

(1) Represents netting under master netting arrangements and a net cash collateral receivable of $- million as of December 31, 2018 and 2017.

(2) Amounts are included in cash and cash equivalents and other property and investments on the Balance Sheets. The fair value of these money market mutual funds approximates cost.

(3) The interest rate derivatives are interest rate locks related to MidAmerican Energy's January 2019 issuance of first mortgage bonds, at which time the interest rate locks were settled for $22 million.

 

MidAmerican Energy's investments in money market mutual funds and debt and equity securities are stated at fair value, with debt securities primarily accounted for as available-for-sale securities. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. In the absence of a quoted market price or net asset value of an identical security, the fair value is determined using pricing models or net asset values based on observable market inputs and quoted market prices of securities with similar characteristics.

 

The following table reconciles the beginning and ending balances of MidAmerican Energy's assets measured at fair value on a recurring basis using significant Level 3 inputs for the years ended December 31 (in millions):

 

 

Commodity Derivatives

 

Auction Rate Securities

 

 

2018

 

2017

 

2018

 

2017

 

 

 

 

 

 

 

 

 

Beginning balance

 

$

3

 

 

$

(2

)

 

$

 

 

$

 

Transfer to affiliate(1)

 

 

 

 

 

 

 

 

Changes included in earnings

 

 

 

 

 

 

 

 

Changes in fair value recognized in OCI

 

 

 

 

 

 

 

 

Changes in fair value recognized in net regulatory assets

 

(3

)

 

2

 

 

 

 

 

Redemptions

 

 

 

 

 

 

 

 

Settlements

 

 

 

3

 

 

 

 

 

Ending balance

 

$

 

 

$

3

 

 

$

 

 

$

 

 

(1) On January 1, 2016, MidAmerican Energy transferred the assets and liabilities of its unregulated retail services business to a subsidiary of BHE.

MidAmerican Energy's long-term debt is carried at cost on the Financial Statements. The fair value of MidAmerican Energy's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of MidAmerican Energy's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of MidAmerican Energy's long-term debt as of December 31 (in millions):

 

2018

 

2017

 

Carrying

Value

 

Fair Value

 

Carrying

Value

 

Fair Value

 

 

 

 

 

 

 

 

Long-term debt

$

5,414

 

 

$

5,644

 

 

$

5,072

 

 

$

5,684

 

 

 

 

 

 

 

(12) Commitments and Contingencies

 

Commitments

 

MidAmerican Energy had the following firm commitments that are not reflected on the Balance Sheet. Minimum payments as of December 31, 2018, are as follows (in millions):

 

 

 

 

 

 

 

 

 

 

 

 

2024 and

 

 

 

 

2019

 

2020

 

2021

 

2022

 

2023

 

Thereafter

 

Total

Contract type:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Coal and natural gas for generation

 

$

96

 

 

$

21

 

 

$

17

 

 

$

13

 

 

$

5

 

 

$

 

 

$

152

 

Electric capacity and transmission

 

29

 

 

28

 

 

26

 

 

15

 

 

7

 

 

36

 

 

141

 

Natural gas contracts for gas operations

 

145

 

 

76

 

 

59

 

 

45

 

 

23

 

 

30

 

 

378

 

Construction commitments

 

1,299

 

 

28

 

 

50

 

 

 

 

 

 

 

 

1,377

 

Easements and operating leases

 

27

 

 

29

 

 

29

 

 

30

 

 

30

 

 

1,078

 

 

1,223

 

Maintenance and services contracts

 

118

 

 

196

 

 

147

 

 

143

 

 

134

 

 

224

 

 

962

 

 

 

$

1,714

 

 

$

378

 

 

$

328

 

 

$

246

 

 

$

199

 

 

$

1,368

 

 

$

4,233

 

 

Coal, Natural Gas, Electric Capacity and Transmission Commitments

 

MidAmerican Energy has coal supply and related transportation and lime contracts for its coal-fueled generating facilities. MidAmerican Energy expects to supplement the coal contracts with additional contracts and spot market purchases to fulfill its future coal supply needs. Additionally, MidAmerican Energy has a natural gas transportation contract for a natural gas-fueled generating facility. The contracts have minimum payment commitments ranging through 2023.

 

MidAmerican Energy has various natural gas supply and transportation contracts for its regulated natural gas operations that have minimum payment commitments ranging through 2037.

 

MidAmerican Energy has contracts to purchase electric capacity that have minimum payment commitments ranging through 2028. MidAmerican Energy also has contracts for the right to transmit electricity over other entities' transmission lines with minimum payment commitments ranging through 2022.

 

Construction Commitments

 

MidAmerican Energy's firm construction commitments reflected in the table above consist primarily of contracts for the construction and repowering of wind-powered generating facilities in 2019.

 

Easements and Operating Leases

 

MidAmerican Energy has non-cancelable easements with minimum payment commitments ranging through 2061 for land in Iowa on which certain of its assets, primarily wind-powered generating facilities, are located. MidAmerican Energy also has non-cancelable operating leases with minimum payment commitments ranging through 2024 primarily for office and other building space. These leases generally require MidAmerican Energy to pay for insurance, taxes and maintenance applicable to the leased property. A number of the leases contain renewal options for varying periods. Rent expense on non-cancelable operating leases totaled $3 million and $3 million for 2018 and 2017, respectively.

 

 

 

 

Maintenance, Services and Other Contracts

 

MidAmerican Energy has other non-cancelable contracts primarily related to maintenance and services for various generating facilities with minimum payment commitments ranging through 2028.

 

Environmental Laws and Regulations

 

MidAmerican Energy is subject to federal, state and local laws and regulations regarding air and water quality, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact its current and future operations. MidAmerican Energy believes it is in material compliance with all applicable laws and regulations.

 

Transmission Rates

 

MidAmerican Energy's wholesale transmission rates are set annually using FERC-approved formula rates subject to true-up for actual cost of service. Prior to September 2016, the rates in effect were based on a 12.38% return on equity ("ROE"). In November 2013 and February 2015, a coalition of intervenors filed successive complaints with the FERC requesting that the 12.38% ROE no longer be found just and reasonable and sought to reduce the base ROE to 9.15% and 8.67%, respectively. MidAmerican Energy is authorized by the FERC to include a 0.50% adder beyond the base ROE effective January 2015. In September 2016, the FERC issued an order for the first complaint, which reduces the base ROE to 10.32% and requires refunds, plus interest, for the period from November 2013 through February 2015. Customer refunds relative to the first complaint occurred in February 2017. It is uncertain when the FERC will rule on the second complaint, covering the period from February 2015 through May 2016. MidAmerican Energy believes it is probable that the FERC will order a base ROE lower than 12.38% in the second complaint and, as of December 31, 2018, has accrued a $10 million liability for refunds of amounts collected under the higher ROE from March 2015 through May 2016.

 

Legal Matters

 

MidAmerican Energy is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. MidAmerican Energy does not believe that such normal and routine litigation will have a material impact on its financial results.

 

 

(13) Components of Accumulated Other Comprehensive Loss, Net

 

The following table shows the change in accumulated other comprehensive loss by each component of other comprehensive income, net of applicable income taxes, for the year ended December 31, 2016 (in millions):

 

 

Unrealized

 

Unrealized

 

Accumulated

 

 

Losses on

 

Losses

 

Other

 

 

Available-For-Sale

 

on Cash Flow

 

Comprehensive

 

 

Securities

 

Hedges

 

Loss, Net

 

 

 

 

 

 

 

Balance, December 31, 2015

 

$

(3

)

 

$

(27

)

 

$

(30

)

Other comprehensive income

 

3

 

 

 

 

3

 

Dividend of unregulated retail services business

 

 

 

27

 

 

27

 

Balance, December 31, 2016

 

$

 

 

$

 

 

$

 

 

On January 1, 2016, MidAmerican Energy transferred the assets and liabilities of its unregulated retail services business to a subsidiary of BHE.

 

(14) Revenue from Contracts with Customers

 

MidAmerican Energy uses a single five-step model to identify and recognizes revenue from contracts with customers ("Customer Revenue") upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which it expects to be entitled in exchange for those goods or services. The following table summarizes MidAmerican Energy's revenue by utility function and customer class, (in millions):

 

For the Year Ended December 31, 2018

 

Electric

 

Natural Gas

 

Other

 

Total

Customer Revenue:

 

 

 

 

 

 

 

Retail:

 

 

 

 

 

 

 

Residential

$

696

 

 

$

421

 

 

$

 

 

$

1,117

 

Commercial

314

 

 

153

 

 

 

 

467

 

Industrial

758

 

 

22

 

 

 

 

780

 

Natural gas transportation services

 

 

39

 

 

 

 

39

 

Other retail

147

 

 

1

 

 

 

 

148

 

Total retail

1,915

 

 

636

 

 

 

 

2,551

 

Wholesale

295

 

 

116

 

 

 

 

411

 

Multi-value transmission projects

55

 

 

 

 

 

 

55

 

Other Customer Revenue

 

 

 

 

11

 

 

11

 

Total Customer Revenue

2,265

 

 

752

 

 

11

 

 

3,028

 

Other revenue

18

 

 

2

 

 

1

 

 

21

 

Total operating revenue

$

2,283

 

 

$

754

 

 

$

12

 

 

$

3,049

 

 

Contract Assets and Liabilities

 

In the event one of the parties to a contract has performed before the other, MidAmerican Energy would recognize a contract asset or contract liability depending on the relationship between MidAmerican Energy's performance and the customer's payment. As of December 31, 2018, there were no contract assets or contract liabilities recorded on the Balance Sheets.

 

 

(15) Related Party Transactions

 

The companies identified as affiliates of MidAmerican Energy are Berkshire Hathaway and its subsidiaries, including BHE and its subsidiaries. The basis for the following transactions is provided for in service agreements between MidAmerican Energy and the affiliates.

 

MidAmerican Energy is reimbursed for charges incurred on behalf of its affiliates. The majority of these reimbursed expenses are for general costs, such as insurance and building rent, and for employee wages, benefits and costs related to corporate functions such as information technology, human resources, treasury, legal and accounting. The amount of such reimbursements was $51 million and $53 million for 2018 and 2017, respectively. Additionally, in 2018, MidAmerican Energy received $15 million from BHE for the transfer of corporate aircraft.

 

MidAmerican Energy reimbursed BHE in the amount of $11 million and $9 million in 2018 and 2017, respectively, for its share of corporate expenses.

 

 

MidAmerican Energy purchases natural gas transportation and storage capacity services from Northern Natural Gas Company, a wholly owned subsidiary of BHE, and coal transportation services from BNSF Railway Company, an indirect wholly owned subsidiary of Berkshire Hathaway, in the normal course of business at either tariffed or market prices. These purchases totaled $127 million and $122 million in 2018 and 2017, respectively.

 

MidAmerican Energy had accounts receivable from affiliates of $8 million and $9 million as of December 31, 2018 and 2017, respectively, that are included in receivables on the Balance Sheets. MidAmerican Energy also had accounts payable to affiliates of $12 million and $16 million as of December 31, 2018 and 2017, respectively, that are included in accounts payable on the Balance Sheets.

 

MidAmerican Energy is party to a tax-sharing agreement and is part of the Berkshire Hathaway consolidated United States federal income tax return. For current federal and state income taxes, MidAmerican Energy had a payable to BHE of $156 million as of December 31, 2018, and a receivable from BHE of $51 million as of December 31, 2017. MidAmerican Energy received net cash receipts for federal and state income taxes from BHE totaling $494 million and $465 million for the years ended December 31, 2018 and 2017, respectively.

 

MidAmerican Energy recognizes the full amount of the funded status for its pension and postretirement plans, and amounts attributable to MidAmerican Energy's affiliates that have not previously been recognized through income are recognized as an intercompany balance with such affiliates. MidAmerican Energy adjusts these balances when changes to the funded status of the respective plans are recognized and does not intend to settle the balances currently. Amounts receivable from affiliates attributable to the funded status of employee benefit plans totaled $20 million and $16 million as of December 31, 2018 and 2017, respectively, and similar amounts payable to affiliates totaled $36 million and $45 million as of December 31, 2018 and 2017, respectively. See Note 9 for further information pertaining to pension and postretirement accounting.


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3
Preceding Quarter/Year to Date Changes in Fair Value
4
Total (lines 2 and 3)
604,542,345
604,542,345
5
Balance of Account 219 at End of Preceding Quarter/Year
6
Balance of Account 219 at Beginning of Current Year
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8
Current Quarter/Year to Date Changes in Fair Value
9
Total (lines 7 and 8)
682,152,887
682,152,887
10
Balance of Account 219 at End of Current Quarter/Year


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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)
14,509,180,454
12,891,623,190
1,617,557,264
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
1,941,881
1,941,881
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
6,350,205,979
6,244,900,379
105,305,600
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
8
UtilityPlantInServiceClassifiedAndUnclassified
Total (3 thru 7)
20,861,328,314
19,136,523,569
1,724,804,745
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
2,927,221
2,927,221
11
ConstructionWorkInProgress
Construction Work in Progress
1,032,184,664
1,022,914,467
9,270,197
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
21,784,315
423,741
21,360,574
13
UtilityPlantAndConstructionWorkInProgress
Total Utility Plant (8 thru 12)
21,918,224,514
20,162,788,998
1,755,435,516
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
6,719,672,910
5,938,574,495
781,098,415
15
UtilityPlantNet
Net Utility Plant (13 less 14)
15,198,551,604
14,224,214,503
974,337,101
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
6,531,201,449
5,792,632,012
738,569,437
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
167,050,098
145,881,694
21,168,404
22
DepreciationAmortizationAndDepletionUtilityPlantInService
Total in Service (18 thru 21)
6,698,251,547
5,938,513,706
759,737,841
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
21,421,363
60,789
21,360,574
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Total Accum Prov (equals 14) (22,26,30,31,32)
6,719,672,910
5,938,574,495
781,098,415


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
1,958,076
3,990,027
(a)
3,876,391
2,071,712
3
Nuclear Materials
1,947
19,626,515
(b)
19,626,514
1,948
4
Allowance for Funds Used during Construction
357,253
137,086
(c)
11,064
483,275
5
(Other Overhead Construction Costs, provide details in footnote)
6
SUBTOTAL (Total 2 thru 5)
2,317,276
23,753,628
2,556,935
7
Nuclear Fuel Materials and Assemblies
8
In Stock (120.2)
21,982,450
(d)
21,982,450
9
In Reactor (120.3)
145,697,038
22,021,963
(e)
25,843,104
141,875,897
10
SUBTOTAL (Total 8 & 9)
145,697,038
44,004,413
141,875,897
11
Spent Nuclear Fuel (120.4)
47,495,730
25,843,104
(f)
21,820,528
51,518,306
12
Nuclear Fuel Under Capital Leases (120.6)
13
(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
145,098,821
1,394,504
146,493,325
14
TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
50,411,223
93,601,145
1,394,504
93,160,051
49,457,813
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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: FabricationCostsNuclearFuelInProcessOfRefinementConversionEnrichmentAndFabricationOtherReductions

Transfer to account 120200

(b) Concept: NuclearMaterialsNuclearFuelInProcessOfRefinementConversionEnrichmentAndFabricationOtherReductions

Transfer to account 120200

(c) Concept: AllowanceForFundsConstructionNuclearFuelInProcessOfRefinementConversionEnrichmentAndFabricationOtherReductions

Transfer to account 120200

(d) Concept: NuclearFuelMaterialsAndAssembliesInStockOtherReductions

Transfer to account 120300

(e) Concept: NuclearFuelAssembliesInReactorOtherReductions

Transfer to account 120400

(f) Concept: SpentNuclearFuelOtherReductions

Transfer to account 120500


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
101,985
101,985
3
(302) Franchise and Consents
407,814
139,879
547,693
4
(303) Miscellaneous Intangible Plant
173,846,133
41,212,247
3,095,119
37
211,963,298
5
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)
174,355,932
41,352,126
3,095,119
37
212,612,976
6
2. PRODUCTION PLANT
7
A. Steam Production Plant
8
(310) Land and Land Rights
9,053,952
39
9,053,991
9
(311) Structures and Improvements
452,648,148
43,802,343
985,269
495,465,222
10
(312) Boiler Plant Equipment
2,148,477,461
62,294,729
51,946,487
2,158,825,703
11
(313) Engines and Engine-Driven Generators
12
(314) Turbogenerator Units
420,335,472
1,173,439
10,156,470
411,352,441
13
(315) Accessory Electric Equipment
191,939,035
29,449,276
2,191,915
219,196,396
14
(316) Misc. Power Plant Equipment
18,258,460
987,689
58,596
19,187,553
15
(317) Asset Retirement Costs for Steam Production
140,949,184
2,873,724
143,822,908
16
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
3,381,661,712
140,581,239
65,338,737
3,456,904,214
17
B. Nuclear Production Plant
18
(320) Land and Land Rights
402,338
402,338
19
(321) Structures and Improvements
42,865,843
8,082,467
17,377
50,930,933
20
(322) Reactor Plant Equipment
292,825,487
8,538,244
39,677
301,324,054
21
(323) Turbogenerator Units
101,807,035
3,755,934
105,562,969
22
(324) Accessory Electric Equipment
39,629,747
1,986,398
5,561
41,610,584
23
(325) Misc. Power Plant Equipment
22,987,416
1,054,047
43,829
23,997,634
24
(326) Asset Retirement Costs for Nuclear Production
25
TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
500,517,866
23,417,090
106,444
523,828,512
26
C. Hydraulic Production Plant
27
(330) Land and Land Rights
3,113
3,113
28
(331) Structures and Improvements
407,857
407,857
29
(332) Reservoirs, Dams, and Waterways
939,221
939,221
30
(333) Water Wheels, Turbines, and Generators
437,948
708,649
45,598
1,100,999
31
(334) Accessory Electric Equipment
511,520
4,346
507,174
32
(335) Misc. Power Plant Equipment
9,909
9,909
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)
2,309,568
708,649
49,944
2,968,273
36
D. Other Production Plant
37
(340) Land and Land Rights
109,145,277
15,680,702
124,825,979
38
(341) Structures and Improvements
45,987,351
482,525
87,016
46,382,860
39
(342) Fuel Holders, Products, and Accessories
17,811,094
512,594
7,301
18,316,387
40
(343) Prime Movers
1,227,753
1,227,753
41
(344) Generators
6,955,304,573
1,294,085,973
23,125,305
13,484
8,226,251,757
42
(345) Accessory Electric Equipment
726,947,181
173,904,061
946,825
5,464,574
905,368,991
43
(346) Misc. Power Plant Equipment
2,372,807
2,372,807
44
(347) Asset Retirement Costs for Other Production
80,907,683
16,251,916
97,159,599
44.1
(348) Energy Storage Equipment - Production
45
TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
7,939,703,719
1,500,917,771
24,166,447
5,451,090
9,421,906,133
46
TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
11,824,192,865
1,665,624,749
89,661,572
5,451,090
13,405,607,132
47
3. Transmission Plant
48
(350) Land and Land Rights
71,678,754
242,496
834
78,929
71,841,487
48.1
(351) Energy Storage Equipment - Transmission
49
(352) Structures and Improvements
44,298,887
1,034,260
77,655
45,255,492
50
(353) Station Equipment
636,934,480
35,767,223
4,168,617
5,451,090
663,081,996
51
(354) Towers and Fixtures
39,549,536
413,392
39,962,928
52
(355) Poles and Fixtures
560,944,397
36,425,757
1,035,651
1,884
596,332,619
53
(356) Overhead Conductors and Devices
475,824,316
34,138,448
749,792
1,884
509,214,856
54
(357) Underground Conduit
1,266,608
1,266,608
55
(358) Underground Conductors and Devices
2,809,045
2,809,045
56
(359) Roads and Trails
154,094
154,094
57
(359.1) Asset Retirement Costs for Transmission Plant
20,448
23,097
2,649
58
TOTAL Transmission Plant (Enter Total of lines 49 thru 59)
1,833,480,565
107,998,479
6,032,549
5,530,019
1,929,916,476
59
4. Distribution Plant
60
(360) Land and Land Rights
17,758,123
2,950,670
37,413
956,189
19,715,191
61
(361) Structures and Improvements
22,721,566
672,133
28,441
23,365,258
62
(362) Station Equipment
487,342,911
28,538,452
2,216,511
443,183
513,221,669
63
(363) Energy Storage Equipment – Distribution
2,416,464
2,416,464
64
(364) Poles, Towers, and Fixtures
382,877,144
40,514,774
1,786,358
421,605,560
65
(365) Overhead Conductors and Devices
544,653,897
31,402,622
5,911,753
570,144,766
66
(366) Underground Conduit
67,310,447
6,083,871
210,523
73,183,795
67
(367) Underground Conductors and Devices
597,539,667
58,097,912
7,245,269
221,931
648,614,241
68
(368) Line Transformers
374,431,919
23,380,716
5,459,048
266,430
392,087,157
69
(369) Services
172,639,103
7,863,715
241,209
180,261,609
70
(370) Meters
71,662,895
2,187,406
445,284
73,405,017
71
(371) Installations on Customer Premises
16,515,645
443,974
267,654
16,691,965
72
(372) Leased Property on Customer Premises
73
(373) Street Lighting and Signal Systems
101,398,410
16,875,167
8,232,440
110,041,137
74
(374) Asset Retirement Costs for Distribution Plant
90,530
217,914
308,444
75
TOTAL Distribution Plant (Enter Total of lines 62 thru 76)
2,856,761,197
221,209,962
32,081,903
1,443,871
3,044,445,385
76
5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77
(380) Land and Land Rights
78
(381) Structures and Improvements
79
(382) Computer Hardware
80
(383) Computer Software
81
(384) Communication Equipment
82
(385) Miscellaneous Regional Transmission and Market Operation Plant
83
(386) Asset Retirement Costs for Regional Transmission and Market Oper
84
TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85
6. General Plant
86
(389) Land and Land Rights
9,927,182
131,716
76,287
1,035,118
11,017,729
87
(390) Structures and Improvements
161,992,063
86,481,504
1,614,820
246,858,747
88
(391) Office Furniture and Equipment
45,284,239
9,253,714
5,716,721
37
48,821,195
89
(392) Transportation Equipment
126,800,506
24,234,865
22,798,143
16,567
128,220,661
90
(393) Stores Equipment
1,137,297
417,723
3,299
1,551,721
91
(394) Tools, Shop and Garage Equipment
27,743,078
10,433,874
583,864
37,593,088
92
(395) Laboratory Equipment
452,600
209,704
3,655
658,649
93
(396) Power Operated Equipment
25,489,283
1,825,424
720,397
54,683
26,539,627
94
(397) Communication Equipment
37,589,677
666,767
338,725
487,681
38,405,400
95
(398) Miscellaneous Equipment
4,015,903
357,923
99,043
4,274,783
96
SUBTOTAL (Enter Total of lines 86 thru 95)
440,431,828
134,013,214
31,954,954
1,451,512
543,941,600
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)
440,431,828
134,013,214
31,954,954
1,451,512
543,941,600
100
TOTAL (Accounts 101 and 106)
17,129,222,387
2,170,198,530
162,826,097
71,251
19,136,523,569
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)
17,129,222,387
2,170,198,530
(a)
162,826,097
71,251
19,136,523,569


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: ElectricPlantInServiceRetirements

 

 

 

Retirements, Page 207, Line 104, Column (d)

$ 162,826,097

Retirement of Leasehold Improvements

 

-567,396

Retirement of Land

 

-114,534

Retirement of Intangible Plant Assets

 

-3,095,119

 

 

 

Retirements, Account 108, Page 219, Line 12, Column (c)

$ 159,049,048

 

 


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Future station site in SE Des Moines
383,739
3
Future station site in Altoona
272,677
4
Future station site in Waukee
270,530
5
Future land site WSEC#3 Council Bluffs
850,484
6
Future station site Mudhollow Rd. in Council Bluffs
260,542
7
Future station site in Ankeny
294,695
8
Six (6) parcels under $250,000 each
594,554
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
2,927,221


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Construct 500MW Orient Wind Farm, Adair County, Iowa
180,111,931
2
Wind turbine repowering, Pomeroy I & II Wind Farm, Pocahontas and Calhoun County, Iowa
118,689,693
3
Wind Farm XI common construction expenses, Iowa
110,403,680
4
Wind turbine repowering, Carroll County, Iowa
109,545,314
5
Construction of Ida Grove II Wind Farm, Ida County, Iowa
73,379,506
6
Construction project for 200MW North English Wind Farm, Poweshiek County , Iowa
35,306,382
7
Construction project for 250MW Palo Alto Wind Farm, Palo Alto County, Iowa
33,761,646
8
Construction of new Dallas County service center phase 2, Dallas County, Iowa
33,008,887
9
Wind XI MISO costs and network upgrade costs, North English Wind Farm, Poweshiek Cnty, IA
29,569,219
10
Wind turbine repowering, Rolling Hills Wind Farm, Adair, Adams and Cass County, Iowa
26,867,645
11
Wind turbine repowering , Adair Wind Farm, Adair and Cass County, Iowa
23,719,317
12
Wind turbine repowering common construction expenses, Iowa
21,446,826
13
Wind turbine repowering, Walnut Wind Farm, Pottawattamie County, Iowa
15,477,103
14
Wind Farm XII common construction expenses, Iowa
11,889,799
15
Remodel Urbandale Business Center to open office concept, Polk County, Iowa
11,826,557
16
Development of 3 applications to improve operational and system performance, Polk Cnty, IA
10,274,259
17
Create the MEC utility Next Generation Transport Network, Polk County, Iowa
8,636,515
18
Wind turbine repowering, Laurel Wind Farm, Marshall County, Iowa
8,178,769
19
Construct a new 345 kV substation, Dallas County, Iowa
8,142,440
20
Establish habitat conservation plan, Wind Farms, Iowa
7,191,795
21
Wind XI MISO costs and network upgrade costs, Orient Wind Farm, Adair County, Iowa
7,094,790
22
Construct 345kV line from Ottumwa Generating Station to Missouri state line
7,034,842
23
Capital expenditures for 25% ownership of Quad Cities Generating Station, Scott Cnty, IA
7,001,438
24
Construction of 161 kV line from Pleasant Corner Substation to Beacon Substation, Iowa
6,289,574
25
Remodel Davenport facility to the open office concept, Scott County, Iowa
6,148,672
26
Purchase of top tower sections for repowering wind farms, Iowa
5,432,348
27
Construction of new 13.2 kV express feeder with parallel 1000MCM wiring, Scott Cnty, IA
4,963,304
28
Construction of new 161 kV wind farm interconnection substation for J438, Poweshiek Cnty, I
4,301,082
29
Convert the OGS bottom ash handling system from wet to dry handling, Wapello County, Iowa
3,940,186
30
Construct 161 kV line, Rising Sun Substation to Altoona NE54th Substation, Iowa
3,648,720
31
Rebuild 7.4 miles of the Clarksville-Waverly Municipal Tap 69 kV line, Iowa
3,620,859
32
Wind turbine repowering, Pomeroy IV Wind Farm, Pocahontas and Calhoun County, Iowa
3,527,788
33
Construction of 161 kV line for transmission source to 54th Ave. Substation, Polk Cnty, IA
3,279,712
34
Add'l 161-13kV 50 MVA transformer & switchgears, Willow Creek Substation, Dallas Cnty, IA
3,244,590
35
Expand the 345 kV substation into a four position ring bus, Polk County, Iowa
3,182,727
36
Replace old small duct bank system in Watson Powell & extend into existing system, Polk Cnt
2,929,124
37
Construct approx. 100 miles of underground fiber cable and associated materials, Plymouth C
2,805,113
38
Purchase, installation and configuration of Cisco equipment, All Jurisdictions
2,610,982
39
Replacement of the two-way mobile and portable field radios, All Jurisdictions
2,203,449
40
Purchase capital parts prior to scheduled major inspection on Electrifarm Unit 2, Black Haw
2,037,426
41
Add 161 kV line breakers at Substation J terminal to Enron/Hills & Substation U, Johnson Cn
1,777,087
42
Remodel Delaware Svc Center to open office concept & remodeling fleet garage, Polk Cnty, IA
1,679,068
43
Ottumwa Generating Station Capital Expenses, Wapello County, Iowa
1,676,623
44
Replace plant lighting with LED's in main plant, precipitator & SDA building, Louisa Cnty,
1,485,124
45
Purchase of materials & engineering/installation of 140 miles of underground fiber cable, I
1,437,581
46
Rebuild the 7.8 mile Prairie City to Monroe 69 kV line, Monroe County, Iowa
1,432,131
47
Install second 345-161 kV transformer at Substation 39, Barstow Substation, Rock Island Cnt
1,400,796
48
Purchase a spare 345-161 kV MVA transformer to replace the spare unit, Johnson County, Iowa
1,293,150
49
Purchase system for CSA's, field crews, and Customer First Operations, All Jurisdictions
1,251,613
50
Replace 345 kV breakers & arresters, install disconnect switches & high-security fence, IA
1,229,793
51
Replace digital fault recorders (DFR's) at nine substations, Iowa
1,079,506
52
Construction of site perimeter upgrades, Louisa County, Iowa
1,058,569
53
Thermal upgrade, Polk County, Iowa
1,045,997
54
Construction of a new distribution substation with 69-13 kV, Scott County, Iowa
1,043,153
55
Purchase eight 161 kV and three 345 kV circuit breakers, Polk County, Iowa
1,008,092
56
Construction of Wind XII, Madison County, Iowa
1,006,708
57
Projects less than $1,000,000 including undistributed administrative and general costs
39,285,467
43
1,022,914,467


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
5,411,224,397
5,411,224,397
2
Depreciation Provisions for Year, Charged to
3
DepreciationExpenseExcludingAdjustments
(403) Depreciation Expense
510,321,668
510,321,668
4
DepreciationExpenseForAssetRetirementCosts
(403.1) Depreciation Expense for Asset Retirement Costs
19,164,522
19,164,522
5
ExpensesOfElectricPlantLeasedToOthers
(413) Exp. of Elec. Plt. Leas. to Others
6
TransportationExpensesClearing
Transportation Expenses-Clearing
6,344,408
6,344,408
7
OtherClearingAccounts
Other Clearing Accounts
378,962
378,962
8
OtherAccounts
Other Accounts (Specify, details in footnote):
9.1
1,912,681
(a)
1,912,681
10
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)
538,122,241
538,122,241
11
Net Charges for Plant Retired:
12
BookCostOfRetiredPlant
Book Cost of Plant Retired
159,049,048
(b)
159,049,048
13
CostOfRemovalOfPlant
Cost of Removal
23,634,310
23,634,310
14
SalvageValueOfRetiredPlant
Salvage (Credit)
21,356,118
21,356,118
15
NetChargesForRetiredPlant
TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)
161,327,240
161,327,240
16
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote):
17.1
47,110,713
(c)
47,110,713
17.2
Net Change in Account
42,498,099
42,498,099
18
BookCostOfAssetRetirementCosts
Book Cost or Asset Retirement Costs Retired
19
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)
5,792,632,012
5,792,632,012
Section B. Balances at End of Year According to Functional Classification
20
AccumulatedDepreciationSteamProduction
Steam Production
1,801,372,757
1,801,372,757
21
AccumulatedDepreciationNuclearProduction
Nuclear Production
257,303,139
257,303,139
22
AccumulatedDepreciationHydraulicProductionConventional
Hydraulic Production-Conventional
2,831,373
2,831,373
23
AccumulatedDepreciationHydraulicProductionPumpedStorage
Hydraulic Production-Pumped Storage
24
AccumulatedDepreciationOtherProduction
Other Production
1,871,984,312
1,871,984,312
25
AccumulatedDepreciationTransmission
Transmission
523,597,398
523,597,398
26
AccumulatedDepreciationDistribution
Distribution
1,169,209,900
1,169,209,900
27
AccumulatedDepreciationRegionalTransmissionAndMarketOperation
Regional Transmission and Market Operation
28
AccumulatedDepreciationGeneral
General
166,333,133
166,333,133
29
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28)
5,792,632,012
5,792,632,012


FOOTNOTE DATA

(a) Concept: OtherAccounts

Charged to account 151 Coal Clearing for depreciation of Railcars.

(b) Concept: BookCostOfRetiredPlant

 

Difference between Line 12, Column [c] and Page 204-207, Line 104, Column [d]

 

 

 

Page 204-207, Line 104, Column [d]

 

162,826,097

Retirement of Intangible Plant Assets

 

(3,095,119)

Retirement of Land

 

(114,534)

Retirement of Leasehold Improvements

 

(567,396)

Page 219, Line 12, Column [c]

 

159,049,048

(c) Concept: OtherAdjustmentsToAccumulatedDepreciation

Other Debit or Credit Items

 

 

 

 

 

Production & Distribution Transfer to Regulatory Assets(108.132)

(1,276,867)

Reclassification to ARO Liability

 

27,899,572

Reserve Adjustment - Property Leased to Others

(56,799)

Reserve Adjustment - Wind X Customer Credit

 

20,547,476

Reclassification of Buliding to Leasehold Improvement

(2,668)

Reclassification of Software to Hardware

 

(1)

Page 219, Line 16, Column[c]

 

47,110,713


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
None
42
Total Cost of Account 123.1 $
Total


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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)
119,853,771
54,794,331
Electric
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)
30,119,635
42,935,265
Electric & Gas
6
Assigned to - Operations and Maintenance
7
Production Plant (Estimated)
59,556,285
62,629,072
Electric
8
Transmission Plant (Estimated)
5,085,207
6,630,042
Electric
9
Distribution Plant (Estimated)
834,889
4,821,390
Electric & Gas
10
Regional Transmission and Market Operation Plant (Estimated)
11
Assigned to - Other (provide details in footnote)
(a)
457,773
521,849
Electric & Gas
12
TOTAL Account 154 (Enter Total of lines 5 thru 11)
96,053,789
117,537,618
Electric & Gas
13
Merchandise (Account 155)
78,996
77,718
Gas
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)
3,982,345
6,511,714
Electric & Gas
17
18
19
20
TOTAL Materials and Supplies
219,968,901
178,921,381


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesOther

 

 

 

2017

2018

Fleet Parts - Delaware

 

$ 27,268

$ 26,815

Fleet Parts - Rock Island

 

100,001

93,777

Fleet Parts - Sioux City Fleet Center

71,910

69,315

Fleet Parts - Council Bluffs

45,865

57,066

Fleet Parts - Walnut Ridge

46,437

43,617

Fleet Parts - Two Rivers

 

42,654

105,102

Fleet Parts - Waterloo

 

37,229

39,633

Fleet Parts - Fort Dodge

 

26,051

23,715

Fleet Parts - Bettendorf

 

29,549

33,163

Fleet Parts - Sioux City Fleet Travel

13,366

12,399

Fleet Parts - Carroll

 

17,443

17,247

 

 

 

 

 

 

 

 

$ 457,773

$ 521,849


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
412,585
899,115
59,139
59,139
59,139
1,537,614
2,127,616
899,115
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
806
39,533
39,533
37,491
91,033
208,396
5
Returned by EPA
6
7
8
Purchases/Transfers:
9
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
(a)
47,884
(b)
64,934
47,884
64,934
19
Other:
20
Allowances Used
20.1
20.2
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
365,507
(c)
834,181
98,672
98,672
96,630
1,628,647
2,288,128
834,181
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
854.7
854.7
854.7
854.7
41,880.3
45,299.1
37
Add: Withheld by EPA
1,709.4
1,709.4
38
Deduct: Returned by EPA
39
Cost of Sales
854.7
854.7
1,709.4
40
Balance-End of Year
854.7
854.7
854.7
42,735
45,299.1
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
859.7
57
854.7
17
1,714.4
74
45
Gains
859.7
57
854.7
17
1,714.4
74
46
Losses


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: ChargesToAllowancesInventoryNumber

Includes 223 allowances attributable to the purchase of additional energy from a joint partner in Walter Scott Energy Center 4. The purchase agreement required that MidAmerican supply the emission allowances for such energy purchases. The $391 cost of such allowances is included in Account 555.

(b) Concept: ChargesToAllowancesInventory

Includes 223 allowances attributable to the purchase of additional energy from a joint partner in Walter Scott Energy Center 4. The purchase agreement required that MidAmerican supply the emission allowances for such energy purchases. The $391 cost of such allowances is included in Account 555.

(c) Concept: AllowanceInventory
Duplicate fact discrepancy. Schedule: 228a - Schedule - Allowances (Accounts 158.1 and 158.2), Row: 3, Column: 58, Value: 0

Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
49,315
49,315
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
565
25,392
25,392
18,370
15,707
85,426
5
Returned by EPA
6
7
8
Purchases/Transfers:
9
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
(a)
17,863
17,863
19
Other:
20
Allowances Used
20.1
20.2
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
32,017
25,392
25,392
18,370
15,707
116,878
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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: ChargesToAllowancesInventoryNumber

Includes 138 allowances attributable to the purchase of additional energy from a joint partner in Walter Scott Energy Center 4. The purchase agreement required that MidAmerican supply the emission allowances for such energy purchases. There are no costs.


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
MRES Atlantic Glacier
3,844
20
Total
21
Generation Studies
22
SHORT CIRCUIT J415
1,329
1,329
23
SHORT CIRCUIT J611
1,287
1,287
24
SHORT CIRCUIT J583
1,287
1,287
25
SHORT CIRCUIT J476
1,329
1,329
26
SHORT CIRCUIT J439
1,329
1,329
27
Int Facilities J535
1,115
1,115
28
Int Facilities J534
1,115
1,115
29
Int Facilities J530
1,115
1,115
30
Int Facilities J528
1,115
1,115
31
Int Facilities J527
1,115
1,115
32
Int Facilities J524
1,757
1,757
33
Int Facilities J506
1,115
1,115
34
Int Facilities J498
35
NU J475 J530
637
637
36
NU J495
975
975
37
NU J498 J524 J534 J535
724
724
38
NU J498
838
838
39
NU J498 J499
938
938
40
NU J524
724
724
41
NU J498 J535
637
637
42
NU J530
274
274
43
NU Bondurant-Montezuma
886
886
44
NU BH and MidPort Caps
1,136
1,136
45
NU Monte Cap
791
791
46
NU Deep River Cap
814
814
39
Total
40 Grand Total


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Unrealized loss on interest rate derivatives
18,871,056
18,871,056
2
Manufactured gas plant sites related costs
6,867,000
6,360,800
376,800
12,851,000
3
QCS/Nuclear fuel - Illinois
3,603,651
240,244
3,363,407
4
Asset retirement obligations
133,018,376
32,920,741
6,280,275
159,658,842
5
Unrealized G/L on electric energy contracts
18,938,136
18,938,136
6
Unrealized G/L on gas energy contracts
6,207,032
43,106,679
48,712,782
600,929
7
Pension liability
5,935,182
5,935,182
8
SERP liability
24,333,887
6,058,481
18,275,406
9
OPEB liability
18,636,383
23,745,636
4,594,755
37,787,264
10
SD farm tap
144,000
130,922
139,975
134,947
11
Iowa depreciation deferral
172,037,810
59,324,526
34,523,960
196,838,376
44
TOTAL
364,848,139
209,333,678
119,865,408
454,316,409


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
DSM Deferral
83,933,542
148,514,358
188,115,276
44,332,624
2
Market Value Adjustment - Gas
14,297,345
20,098,801
23,530,392
10,865,754
3
Deferred Issue Cost
1,181,371
607,497
734,956
1,053,912
4
GDMEC Long-term Maint. Prgm.
8,585,552
540,600
8,044,952
5
Portable Power Module
228,996
85,720
163,373
151,343
6
Federal and State income tax
2,344,329
308,435
2,652,764
7
Deferred Debt Refinancing
1,003,329
834,155
169,174
8
OH to Underground Conversions
1,642
298
1,188
2,532
9
Illinois Rate 2013
19,303
10,071
9,232
10
Siemens Maintenance
6,723,676
82,622,643
80,042,142
9,304,177
11
Long Term Receivable MISO
1,141,914
1,141,914
12
Miscellaneous
123,668
47,489
76,179
47
Miscellaneous Work in Progress
48
Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49
TOTAL
118,578,054
75,146,729


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
ASC 740 Deferred Taxes
7,845,867
7,164,726
3
4
Other (Reg Assets & Liabilities Deferred Income Taxes)
119,878,617
115,059,375
5
Other (ASC 740)
161,686,869
145,930,060
6
Other (Nonproperty Deferred Income Taxes):
71,061,986
82,135,505
7
7
Other
8 TOTAL Electric (Enter Total of lines 2 thru 7)
360,473,339
350,289,666
9
Other (Specify)
10
ASC 740 Deferred Taxes
1,041,253
952,965
11
12
Other (Reg Assets & Liabilities Deferred Income Taxes)
8,630,168
5,145,632
13
Other (ASC 740)
17,155,109
17,336,979
14
Other (Nonproperty Deferred Income Taxes):
38,453,262
33,856,134
15
15
Other
16 TOTAL Gas (Enter Total of lines 10 thru 15)
65,279,792
57,291,710
17 Other (Specify)
18 TOTAL (Acct 190) (Total of lines 8, 16 and 17)
451,261,769
(a)
434,043,681
Notes


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxes

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

ADIT-190

Total

Gas, Prod

Only

 

 

 

 

Or Other

Transmission

Plant

Labor

 

 

Related

Related

Related

Related

 

 

Retail

 

 

 

 

 

 

 

 

 

Regulated

 

 

 

 

 

ARO Liability

44,589,272

44,589,272

 

 

 

Reserve for Bad Debts

2,159,915

2,159,915

 

 

 

Accrued Vacation

5,144,530

2,651,891

 

 

2,492,639

Deferred Compensation - Non Current

24,581,928

12,754,722

 

 

11,827,207

LTIP Mark to Mkt Gain / Loss - Inc Stmt

(602,791)

(312,745)

 

 

(290,046)

LT Incentive Plan - non current

5,065,312

2,628,217

 

 

2,437,095

Accrued Liability - Emission Fees

508,323

508,323

 

 

 

Accrued Non Current Liability

(82,795)

210,394

 

(293,189)

 

Deferred Compensation - Current

2,910,115

1,509,959

 

 

1,400,156

Deferred MVP Transmission O/U

(1,655,721)

 

(1,655,721)

 

 

Deferred Severance

17,635

12,091

 

 

5,544

Derivative Hedge - Loss

5,395,984

5,395,984

 

 

 

Gas Contracts Liability

167,827

167,827

 

 

 

Gas Inventory

2,435,004

2,435,004

 

 

 

Gross-up on Refundable Advances (CIAC)

11,435

11,435

 

 

 

State NOL Carryforwards

36,174,557

4,818,909

 

31,355,649

 

Kansas Property Tax Reserve

69,183

69,183

 

 

 

LT Services Agreement

7,786,747

7,786,747

 

 

 

Nuclear Decommissioning

3,420

3,420

 

 

 

OPEB Liability

10,553,169

2,954,888

 

 

7,598,281

Pension Liability

1,657,568

464,119

 

 

1,193,449

Pension Unrecognized Gain / Loss - FAS 158 Inc Stmt

(10,114,771)

(5,251,833)

 

 

(4,862,938)

QCS Nuclear Fuel

939,327

939,327

 

 

 

Refund Accrual

3,451,961

1,420,800

2,031,160

 

 

Renewable Advantage- Deferred Credit

67,797

67,797

 

 

 

Reserve for Public Liability

232,266

3,217

 

229,050

 

RL - ARO

42,292,308

42,292,308

 

 

 

RL - Electric Contracts

10,333

10,333

 

 

 

RL - Iowa Revenue Sharing 2

20,860,888

 

 

20,860,888

 

RL - MFG Gas

1,917,805

1,917,805

 

 

 

RL - Nuclear Self Insurance Reserve

1,625,512

1,625,512

 

 

 

RL - QC Station Outage Reserve

2,479,204

2,479,204

 

 

 

SERP Liab

5,103,927

1,429,100

 

 

3,674,827

Transmission - Deferred Credit

3,565

 

3,565

 

 

Unbilled Revenue

8,985,907

8,985,907

 

 

 

Workers Compensation

1,954,709

1,032,868

 

 

921,841

 

 

 

 

 

 

Nonregulated

 

 

 

 

 

Contribution in Aid of Construction

62,986,543

15,224,749

 

47,761,794

 

Debt AFUDC

(1,504)

(1,504)

 

 

 

State NOL Carryforward

3,529,494

545,100

 

2,984,394

 

Federal Tax Depreciation - CIAC

(34,625,640)

(8,527,174)

 

(26,098,466)

 

Gross-up on Refundable Advances (CIAC)

2,531,751

939,028

 

1,592,724

 

State Charitable Contribution Carryforward

45,188

6,649

 

38,539

 

Investment Impairment

13,657

13,657

 

 

 

Prior Year State Tax Pmts/Receipts

101

-

 

101

 

RL - EADIT Carry Charge

8,242

8,242

 

 

 

State Tax Depreciation - CIAC

(8,025,528)

(1,948,939)

 

(6,076,589)

 

 

 

 

 

 

 

FAS109 - Reg Liability

171,384,730

171,384,730

 

 

 

RA - FIN 48

9,495,293

9,495,293

 

 

 

 

 

 

 

 

 

Subtotal - p234

434,043,682

334,911,729

379,005

72,354,893

26,398,055

Less FASB 109 (ASC 740)

180,880,024

180,880,024

-

-

-

Less FASB 106 (ASC 740)

 

 

 

 

 

Total

253,163,658

154,031,705

379,005

72,354,893

26,398,055


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
564,725,056
6
Preferred Stock (Account 204)
7
8
9
10
Total
1
Capital Stock (Accounts 201 and 204) - Data Conversion
2
Account 201
3
Common Stock
350,000,000
70,980,203
564,725,056
4
Total Common
350,000,000
70,980,203
564,725,056
5
Account 204
6
None
7
Total


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
19.1
IncreasesDecreasesInOtherPaidInCapital
Account 210 - Gain on cancellation of reacquired capital stock
19.2
IncreasesDecreasesInOtherPaidInCapital
Cancellation of reacquired preferred stock - balance at beg of year
348,607
19.3
IncreasesDecreasesInOtherPaidInCapital
Account 211 - Miscellaneous Paid-In Capital
19.4
IncreasesDecreasesInOtherPaidInCapital
Executive incentive stock options
588,802
19.5
IncreasesDecreasesInOtherPaidInCapital
Loss on repurchase of shares
46,141
19.6
IncreasesDecreasesInOtherPaidInCapital
Adjustment of transfer to Midwest Capital Group
232,465
19.7
IncreasesDecreasesInOtherPaidInCapital
(InterCoast Capital Comp merged with Midwest Capital Group)
20
OtherPaidInCapitalDetail
Ending Balance Amount
40
OtherPaidInCapital
Total
1,123,733


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Common Shares
4,476,219
22
TOTAL
4,476,219


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
4,370,325,000
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
1,056,363,576
Long Term Debt (Historical Data)
1
Account 221 - Bonds
2
Debentures/Pollution Control Revenue Bonds
3
Louisa County, IA - Adjustable Tender Bond - Rate due 2024
34,900,000
254,988
(c)
10/01/1994
(aa)
10/01/2024
(az)
10/01/1994
(bx)
10/01/2024
34,900,000
501,145
4
Pollution Control Bonds:
5
Variable Rate due 2023
6,850,000
176,575
(d)
03/17/1993
(ab)
01/01/2023
(ba)
03/17/1993
(by)
01/01/2023
6,850,000
98,171
6
CP Bonds due 2025
12,750,000
192,139
(e)
01/01/1995
(ac)
01/01/2025
(bb)
01/01/1995
(bz)
01/01/2025
12,750,000
182,727
7
Variable Rate Series A due 2038
45,100,000
380,803
(f)
07/01/2008
(ad)
07/01/2038
(bc)
07/01/2008
(ca)
07/01/2038
45,100,000
666,207
8
Variable Rate Series B due 2023
57,325,000
342,801
(g)
07/01/2008
(ae)
05/01/2023
(bd)
07/01/2008
(cb)
05/01/2023
57,325,000
818,020
9
Variable Rate Series A due 2036
33,400,000
490,388
(h)
09/01/2016
(af)
09/01/2036
(be)
09/01/2016
(cc)
09/01/2036
33,400,000
476,614
10
Variable Rate Series B due 2046
30,000,000
559,155
(i)
12/01/2016
(ag)
12/01/2046
(bf)
12/01/2016
(cd)
12/01/2046
30,000,000
443,153
11
Variable Rate Series 2017 due 2047
150,000,000
1,032,271
(j)
12/13/2017
(ah)
12/01/2047
(bg)
12/13/2017
(ce)
12/01/2047
150,000,000
2,214,452
12
First Mortgage Bonds:
13
Bonds due 2019
350,000,000
196,000
(k)
09/19/2013
(ai)
03/15/2019
(bh)
09/19/2013
(cf)
03/15/2019
350,000,000
8,400,000
14
(Commission Authorization ES13-30-000, Jul 16, 2013)
2,510,395
15
Bonds due 2023
250,000,000
825,000
(l)
09/19/2013
(aj)
09/15/2023
(bi)
09/19/2013
(cg)
09/15/2023
250,000,000
9,250,000
16
(Commission Authorization ES13-30-000, Jul 16, 2013)
2,043,283
17
Bonds due 2043
350,000,000
1,652,000
(m)
09/19/2013
(ak)
09/15/2043
(bj)
09/19/2013
(ch)
09/15/2043
350,000,000
16,800,000
18
(Commission Authorization ES13-30-000, Jul 16, 2013)
3,560,394
19
Bonds due 2019 - 2
150,000,000
1,336,500
(n)
04/03/2014
(al)
03/15/2019
(bk)
04/03/2014
(ci)
03/15/2019
150,000,000
3,600,000
20
(Commission Authorization ES14-4-000, Dec 16, 2013)
1,095,381
21
Bonds due 2024
300,000,000
1,467,000
(o)
04/03/2014
(am)
10/15/2024
(bl)
04/03/2014
(cj)
10/15/2024
300,000,000
10,500,000
22
(Commission Authorization ES14-4-000, Dec 16, 2013)
2,357,654
23
Bonds due 2044
400,000,000
2,404,000
(p)
04/03/2014
(an)
10/15/2044
(bm)
04/03/2014
(ck)
10/15/2044
400,000,000
17,600,000
24
(Commission Authorization ES14-4-000, Dec 16, 2013)
4,030,443
25
Bonds due 2024 - 2
200,000,000
1,707,219
(q)
10/15/2015
(ao)
10/15/2024
(bn)
10/15/2015
(cl)
10/15/2024
200,000,000
7,000,000
26
(Commission Authorization ES15-8-000, Mar 16, 2015)
6,716,000
27
Bonds due 2046
450,000,000
4,970,709
(r)
10/15/2015
(ap)
05/01/2046
(bo)
10/15/2015
(cm)
05/01/2046
450,000,000
19,125,000
28
(Commission Authorization ES15-8-000, Mar 16, 2015)
621,000
29
Bonds due 2027
375,000,000
3,060,989
(s)
02/01/2017
(aq)
05/01/2027
(bp)
02/01/2017
(cn)
05/01/2027
375,000,000
11,625,000
30
(Commission Authorization ES15-8-000, Mar 16, 2015)
119,024
31
Bonds due 2047
475,000,000
4,827,179
(t)
02/01/2017
(ar)
08/01/2047
(bq)
02/01/2017
(co)
08/01/2047
475,000,000
18,762,500
32
(Commission Authorization ES17-39-000, Aug 28, 2017)
667,920
33
Bonds due 2048
700,000,000
6,530,974
(u)
02/01/2018
(as)
08/01/2048
(br)
02/01/2018
(cp)
02/01/2048
700,000,000
23,420,833
34
(Commission Authorization ES17-39-000, Aug 28, 2017)
6,094,303
35
Account 224 - Other Long-Term Debt
36
Medium Term Note Fixed Rate due 2031
400,000,000
3,827,361
(v)
02/08/2002
(at)
12/30/2031
(bs)
02/08/2002
(cq)
01/30/2031
400,000,000
27,000,000
37
(Commission Authorization ES00-51-000, Sep 21, 2000)
5,027,377
38
Medium Term Note Fixed Rate due 2035
300,000,000
4,587,941
(w)
11/01/2005
(au)
11/01/2035
(bt)
11/01/2005
(cr)
11/01/2035
300,000,000
17,250,000
39
(Commission Authorization ES03-60-000, Dec 1, 2003)
258,000
40
Medium Term Note Fixed Rate due 2036
350,000,000
3,315,372
(x)
10/06/2006
(av)
10/15/2036
(bu)
10/06/2006
(cs)
10/15/2036
350,000,000
20,300,000
41
(Commission Authorization ES04-45-000, Nov 10, 2004)
560,000
42
Medium Term Note Fixed Rate due 2018
350,000,000
2,273,536
(y)
03/25/2008
(aw)
03/15/2018
(bv)
03/25/2008
(ct)
03/15/2018
3,813,056
43
(Commission Authorization ES 07-30-000, May 14, 2007)
1,203,501
44
Wellsburg due 2035
5,642,640
1,922,925
(ax)
05/01/2035
(cu)
05/01/2035
3,614,104
45
(a)
(See Note 1)
46
Vienna Wind Farm due 2036
4,343,736
1,233,844
(z)
10/01/2016
(ay)
09/17/2036
(bw)
10/01/2016
(cv)
09/17/2036
2,749,472
47
(b)
(See Note 2)
33 TOTAL
5,780,311,376
80,344,906
5,426,688,576
219,846,878


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: ClassAndSeriesOfObligationCouponRateDescription

MidAmerican Energy Company entered into a facilities service agreement with ITC Midwest LLC on December 23, 2014 for MISO approved project H021. The terms of the agreement compensate ITC Midwest LLC for changes and additions to its transmission system for necessary interconnection service at its facility, to permit MidAmerican Energy Company's electricity generated at the Wellsburg Wind Farm to obtain transmission grid access. The service agreement ends in 2035. Its present value is being amortized over 20 years.

(b) Concept: ClassAndSeriesOfObligationCouponRateDescription

MidAmerican Energy Company entered into a facilities service agreement with ITC Midwest LLC on October 17, 2015 for MISO approved project H009. The terms of the agreement compensate ITC Midwest LLC for changes and additions to its transmission system for necessary interconnection service at its facility, to permit MidAmerican Energy Company's electricity generated at the Vienna Wind Farm to obtain transmission grid access. The service agreement ends in 2036. Its present value is being amortized over 20 years.

(c) Concept: NominalDateOfIssue
Original value: 10/1/1994
(d) Concept: NominalDateOfIssue
Original value: 3/17/1993
(e) Concept: NominalDateOfIssue
Original value: 1/1/1995
(f) Concept: NominalDateOfIssue
Original value: 7/1/2008
(g) Concept: NominalDateOfIssue
Original value: 7/1/2008
(h) Concept: NominalDateOfIssue
Original value: 9/1/2016
(i) Concept: NominalDateOfIssue
Original value: 12/1/2016
(j) Concept: NominalDateOfIssue
Original value: 12/13/2017
(k) Concept: NominalDateOfIssue
Original value: 9/19/2013
(l) Concept: NominalDateOfIssue
Original value: 9/19/2013
(m) Concept: NominalDateOfIssue
Original value: 9/19/2013
(n) Concept: NominalDateOfIssue
Original value: 4/3/2014
(o) Concept: NominalDateOfIssue
Original value: 4/3/2014
(p) Concept: NominalDateOfIssue
Original value: 4/3/2014
(q) Concept: NominalDateOfIssue
Original value: 10/15/2015
(r) Concept: NominalDateOfIssue
Original value: 10/15/2015
(s) Concept: NominalDateOfIssue
Original value: 2/1/2017
(t) Concept: NominalDateOfIssue
Original value: 2/1/2017
(u) Concept: NominalDateOfIssue
Original value: 2/1/2018
(v) Concept: NominalDateOfIssue
Original value: 2/8/2002
(w) Concept: NominalDateOfIssue
Original value: 11/1/2005
(x) Concept: NominalDateOfIssue
Original value: 10/6/2006
(y) Concept: NominalDateOfIssue
Original value: 3/25/2008
(z) Concept: NominalDateOfIssue
Original value: 10/1/2016
(aa) Concept: DateOfMaturity
Original value: 10/1/2024
(ab) Concept: DateOfMaturity
Original value: 1/1/2023
(ac) Concept: DateOfMaturity
Original value: 1/1/2025
(ad) Concept: DateOfMaturity
Original value: 7/1/2038
(ae) Concept: DateOfMaturity
Original value: 5/1/2023
(af) Concept: DateOfMaturity
Original value: 9/1/2036
(ag) Concept: DateOfMaturity
Original value: 12/1/2046
(ah) Concept: DateOfMaturity
Original value: 12/1/2047
(ai) Concept: DateOfMaturity
Original value: 3/15/2019
(aj) Concept: DateOfMaturity
Original value: 9/15/2023
(ak) Concept: DateOfMaturity
Original value: 9/15/2043
(al) Concept: DateOfMaturity
Original value: 3/15/2019
(am) Concept: DateOfMaturity
Original value: 10/15/2024
(an) Concept: DateOfMaturity
Original value: 10/15/2044
(ao) Concept: DateOfMaturity
Original value: 10/15/2024
(ap) Concept: DateOfMaturity
Original value: 5/1/2046
(aq) Concept: DateOfMaturity
Original value: 5/1/2027
(ar) Concept: DateOfMaturity
Original value: 8/1/2047
(as) Concept: DateOfMaturity
Original value: 8/1/2048
(at) Concept: DateOfMaturity
Original value: 12/30/2031
(au) Concept: DateOfMaturity
Original value: 11/1/2035
(av) Concept: DateOfMaturity
Original value: 10/15/2036
(aw) Concept: DateOfMaturity
Original value: 3/15/2018
(ax) Concept: DateOfMaturity
Original value: 5/1/2035
(ay) Concept: DateOfMaturity
Original value: 9/17/2036
(az) Concept: AmortizationPeriodStartDate
Original value: 10/1/1994
(ba) Concept: AmortizationPeriodStartDate
Original value: 3/17/1993
(bb) Concept: AmortizationPeriodStartDate
Original value: 1/1/1995
(bc) Concept: AmortizationPeriodStartDate
Original value: 7/1/2008
(bd) Concept: AmortizationPeriodStartDate
Original value: 7/1/2008
(be) Concept: AmortizationPeriodStartDate
Original value: 9/1/2016
(bf) Concept: AmortizationPeriodStartDate
Original value: 12/1/2016
(bg) Concept: AmortizationPeriodStartDate
Original value: 12/13/2017
(bh) Concept: AmortizationPeriodStartDate
Original value: 9/19/2013
(bi) Concept: AmortizationPeriodStartDate
Original value: 9/19/2013
(bj) Concept: AmortizationPeriodStartDate
Original value: 9/19/2013
(bk) Concept: AmortizationPeriodStartDate
Original value: 4/3/2014
(bl) Concept: AmortizationPeriodStartDate
Original value: 4/3/2014
(bm) Concept: AmortizationPeriodStartDate
Original value: 4/3/2014
(bn) Concept: AmortizationPeriodStartDate
Original value: 10/15/2015
(bo) Concept: AmortizationPeriodStartDate
Original value: 10/15/2015
(bp) Concept: AmortizationPeriodStartDate
Original value: 2/1/2017
(bq) Concept: AmortizationPeriodStartDate
Original value: 2/1/2017
(br) Concept: AmortizationPeriodStartDate
Original value: 2/1/2018
(bs) Concept: AmortizationPeriodStartDate
Original value: 2/8/2002
(bt) Concept: AmortizationPeriodStartDate
Original value: 11/1/2005
(bu) Concept: AmortizationPeriodStartDate
Original value: 10/6/2006
(bv) Concept: AmortizationPeriodStartDate
Original value: 3/25/2008
(bw) Concept: AmortizationPeriodStartDate
Original value: 10/1/2016
(bx) Concept: AmortizationPeriodEndDate
Original value: 10/1/2024
(by) Concept: AmortizationPeriodEndDate
Original value: 1/1/2023
(bz) Concept: AmortizationPeriodEndDate
Original value: 1/1/2025
(ca) Concept: AmortizationPeriodEndDate
Original value: 7/1/2038
(cb) Concept: AmortizationPeriodEndDate
Original value: 5/1/2023
(cc) Concept: AmortizationPeriodEndDate
Original value: 9/1/2036
(cd) Concept: AmortizationPeriodEndDate
Original value: 12/1/2046
(ce) Concept: AmortizationPeriodEndDate
Original value: 12/1/2047
(cf) Concept: AmortizationPeriodEndDate
Original value: 3/15/2019
(cg) Concept: AmortizationPeriodEndDate
Original value: 9/15/2023
(ch) Concept: AmortizationPeriodEndDate
Original value: 9/15/2043
(ci) Concept: AmortizationPeriodEndDate
Original value: 3/15/2019
(cj) Concept: AmortizationPeriodEndDate
Original value: 10/15/2024
(ck) Concept: AmortizationPeriodEndDate
Original value: 10/15/2044
(cl) Concept: AmortizationPeriodEndDate
Original value: 10/15/2024
(cm) Concept: AmortizationPeriodEndDate
Original value: 5/1/2046
(cn) Concept: AmortizationPeriodEndDate
Original value: 5/1/2027
(co) Concept: AmortizationPeriodEndDate
Original value: 8/1/2047
(cp) Concept: AmortizationPeriodEndDate
Original value: 2/1/2048
(cq) Concept: AmortizationPeriodEndDate
Original value: 1/30/2031
(cr) Concept: AmortizationPeriodEndDate
Original value: 11/1/2035
(cs) Concept: AmortizationPeriodEndDate
Original value: 10/15/2036
(ct) Concept: AmortizationPeriodEndDate
Original value: 3/15/2018
(cu) Concept: AmortizationPeriodEndDate
Original value: 5/1/2035
(cv) Concept: AmortizationPeriodEndDate
Original value: 9/17/2036

Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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)
682,152,887
2
Reconciling Items for the Year
3
4
Taxable Income Not Reported on Books
5
Contribution in Aid of Construction
16,104,748
9
Deductions Recorded on Books Not Deducted for Return
10
Deferred Taxes
42,273,538
11
50% Meals and Entertainment
882,343
12
Accrued Non Current Liability
371,584
13
Other
(a)
653,048,160
14
Income Recorded on Books Not Included in Return
15
Current taxes & ITC - Federal
285,223,659
16
Book Fixed Asset Gain/Loss
361,669
17
Debt AFUDC
20,001,820
18
Other
(b)
94,924,762
19
Deductions on Return Not Charged Against Book Income
20
Cost of Removal
70,236,143
21
Equity AFUDC Contra
313,858
22
Federal Tax Deprec - Pollution Control
18,604,736
23
Federal Tax Depreciation
724,991,660
24
Federal Tax Depreciation - CIAC
5,836,442
25
Other
(c)
58,977,360
26
Income on Return Not Charged Agaisnt Book Income
(d)
113,872,422
27
Federal Tax Net Income
229,233,572
28
Show Computation of Tax:
29
Federal Taxable Income
229,233,572
30
Federal Statutory Rate
21
31
Federal Income Tax
48,139,050
32
Prior Year Adjustments
23,779,190
33
Production Tax Credits
308,339,212
34
Investment Tax Credits
35
Federal Income Tax Accrual
(e)
283,979,352


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: DeductionsRecordedOnBooksNotDeductedForReturn

Other Deductions Recorded on Books Not Deducted for Return:

 

 

 

 

Airplane Disallowance

 

2,189,724

Billed PGA/EAC

 

16,170,534

Book Depreciation

 

520,163,247

Book Depreciation - Pollution Control

6,073,902

Book Depreciation Charged to Clearing

11,222,990

Debt AFUDC Contra

 

100,749

Gain/Loss on Reacquired Debt

 

1,190,340

Golden Parachute Payments

 

365,695

Gross-up on Refundable Advances (CIAC)

407,346

Lobbying Expenses

 

1,022,253

LT Services Agreement

 

1,056,351

Nondeductible Parking Costs

 

800,000

Nuclear Fuel Amortization

 

23,215,032

RL - EADIT Carry Charge

 

29,511

RL - Iowa Revenue Sharing

 

44,445,000

Unclassified Labor

 

4,048,009

Wind X Cust Credit Reserve

 

20,547,477

Total

 

 

653,048,160

(b) Concept: IncomeRecordedOnBooksNotIncludedInReturn

Other Income Recorded on Books Not Included in Return:

 

 

 

 

 

 

Deferred Compensation - Current

 

152,627

Deferred Intercompany Gain

 

 

10,793,355

Equity AFUDC-Temp

 

 

53,857,248

Officer's Life Insurance

 

 

6,170,878

Pension Unrecognized Gain/Loss - ASC 715 Inc Stmt

11,432,754

Prior Year State Tax Pmts/Rcpts

 

11,357,528

Interest Income - ASC 740

 

 

1,160,372

Total

 

 

 

94,924,762

(c) Concept: DeductionsOnReturnNotChargedAgainstBookIncome

Other Deductions on Return Not Charged Against Book Income

 

Deferred Compensation - Non Current 2,633,422

Deferred MVP Transmission O/U 1,445,693

LT Incentive Plan - NC 525,891

Repairs Deduction 36,017,188

RL - QC Station Outage Reserve 540,300

Sec 263A - Mixed Service Costs 9,362,471

Texas Gross Receipts Tax 50,000

Unbilled Revenue 8,402,395

58,977,360

(d) Concept: DeductionsOnReturnNotChargedAgainstBookIncome

Income on Return Not Charged Against Book Income

 

 

 

 

Demand Side Management - Current

43,427,866

Federal Tax Fixed Asset Gain/Loss

11,926,641

Iowa Revenue Sharing - Property

16,925,384

Refund Accrual

 

 

4,160,361

Sec 263A - Capitalized Int

 

33,986,329

State Tax adjustment

 

3,445,841

 

 

 

113,872,422

(e) Concept: ComputationOfTax

BHE Sub-Group:

 

 

 

ABA Holding, LLC

CE Butte Energy LLC

FRTC, LLC

 

ABA Management, L.L.C.

CE Electric (NY), Inc

Geronimo Community Solar Gardens Holding Company, LLC

 

Alamo 6 Solar Holdings, LLC

CE Gen Oil Company

Geronimo Community Solar Gardens, LLC

 

Alamo 6, LLC

CE Gen Pipeline Corporation

Gibraltar Title Services, LLC

 

Alaska Gas Transmission Company, LLC

CE Gen Power Corporation

Glenrock Coal Company

 

Allie Beth Allman Real Estate, Ltd

CE Generation LLC

GPWH Holdings, LLC

 

Ambassador Real Estate Company

CE Geothermal, Inc.

Grande Prairie Land Holding, LLC

 

Ambassador Real Estate-Lincoln, LLC

CE International Investments, Inc

Grande Prairie Wind Holdings, LLC

 

Apex Home Maintenance, LLC

CE Leathers Company

Grande Prairie Wind II, LLC

 

ARE Commercial Real Estate, LLC

CE Obsidian Energy LLC

Grande Prairie Wind, LLC

 

ARE Iowa, LLC

CE Obsidian Holding LLC

Greystone Partners of Virginia, LLC

 

Arizona HomeServices, LLC

CE Red Island Energy Holdings LLC

Guarantee Appraisal Corporation

 

Attorneys Title Holdings, Incorporated

CE Red Island Energy LLC

Guarantee Real Estate

 

Berkshire Hathaway Energy Company

CE Salton Sea Inc

HMSV Financial Services, Inc

 

BG Energy Holding Company LLC

CE Texas Energy, LLC

HN Real Estate Group N.C., Inc

 

BH2H Holdings, LLC

CE Texas Fuel LLC

HN Real Estate Group, LLC

 

BHE AC Holding, LLC

CE Texas Pipeline LLC

HN Referral Corporation

 

BHE America Transco, LLC

CE Texas Power LLC

Home Service Connections, LLC

 

BHE Canada LLC

CE Texas Resources LLC

HomeServices Insurance Agency, LLC

 

BHE Community Solar, LLC

CE Turbo LLC

HomeServices Insurance, Inc

 

BHE Gas, Inc.

Champion Realty, Inc

HomeServices Lending, LLC

 

BHE Geothermal, LLC

Chancellor Title Services, Inc

HomeServices MidAtlantic, LLC

 

BHE Hydro, LLC

Columbia Title of Florida, Inc

HomeServices Northeast, LLC

 

BHE Midcontinent Transmission Holdings LLC

Commonsite, Inc.

HomeServices of Alabama, Inc.

 

BHE Pearl Solar Holdings, LLC

Conejo Energy Company

HomeServices of America, Inc

 

BHE Pearl Solar, LLC

Cordova Energy Company, LLC

HomeServices of California, Inc

 

BHE Renewables, LLC

CTHM, L.L.C.

HomeServices of Colorado, LLC

 

BHE Solar, LLC

CTRE, L.L.C.

HomeServices of Connecticut, LLC

 

BHE Southwest Transmission Holdings LLC

Dakota Dunes Development Company

HomeServices of Florida, Inc

 

BHE Texas Transco, LLC

DCCO, Inc

HomeServices of Georgia, LLC

 

BHE U.K. Electric, Inc

Del Ranch Company

HomeServices of Illinois Holdings, LLC

 

BHE U.K. Inc

Denver Rental, LLC

HomeServices of Illinois, LLC

 

BHE U.K. Power, Inc

Desert Valley Company

HomeServices of Iowa, Inc

 

BHE U.S. Transmission, LLC

DG-SB Project Holdings, LLC

HomeServices of Kentucky Real Estate Academy, LLC

 

BHE Wind, LLC

Ebby Alumni Group, Inc

HomeServices of Kentucky, Inc

 

BHER Power Resources, Inc.

Ebby Halliday Properties, Inc

HomeServices of Minnesota, LLC

 

BHER Santa Rita Holdings, LLC

Ebby Halliday Real Estate, Inc.

HomeServices of MOKAN, LLC

 

BHER Santa Rita Investment, LLC

Edina Financial Services, Inc

HomeServices of Nebraska, Inc

 

BHER Santa Rita Tax, Inc.

Edina Realty Insurance, LLC

HomeServices of New Jersey, LLC

 

BHES CSG Holdings, LLC

Edina Realty Referral Network, Inc

HomeServices of New York, LLC

 

BHES Pearl Solar Holdings, LLC

Edina Realty Title, Inc

HomeServices of Oregon, LLC

 

BHH KC Real Estate, LLC

Edina Realty, Inc

HomeServices of Texas, LLC

 

Big Spring Pipeline Company

Elmore Company

HomeServices of the Carolinas, Inc

 

Bishop Hill Energy II, LLC

Energy West Mining Company

HomeServices of Washington, LLC

 

Bishop Hill II Holdings, LLC

Esslinger-Wooten-Maxwell, Inc

HomeServices of Wisconsin, LLC

 

CalEnergy Company, Inc

E-W-M Referral Services, Inc.

HomeServices Referral Network, LLC

 

CalEnergy Generation Operating Company

F&R/T LLC

HomeServices Relocation, LLC

 

CalEnergy International Services, Inc

Falcon Power Operating Company

Houlihan/Lawrence Inc.

 

CalEnergy Minerals LLC

FFR, Inc

HS Franchise Holding, LLC

 

CalEnergy Operating Corporation

First Network Realty, Inc.

HSF Affiliates LLC

 

CalEnergy Pacific Holdings Corp

First Realty Group, Inc.

HSGA Real Estate Group, L.L.C.

 

California Energy Development Corporation

First Realty, Ltd

HSN Holding, LLC

 

California Energy Management Company

First Reserve Insurance, Inc

HSTX Title, LLC

 

California Energy Yuma Corporation

First Weber Illinois, LLC

HSW Affiliates Holding, LLC

 

California Utility Holdco, LLC

First Weber, Inc.

Huff Commercial Group, LLC

 

Capitol Title Company

Florida Network LLC

Huff-Drees Realty, Inc

 

CBSHome Real Estate Company

Florida Network Property Management, LLC

IES Holding II LLC

 

CBSHome Real Estate of Iowa, Inc

For Rent, Inc

IMO Company, Inc

 

CE Black Rock Holdings LLC

Fort Dearborn Land Title Company, LLC

Imperial Magma LLC

 

CE Butte Energy Holdings LLC

Fossil Rock Fuels, LLC

Intero Franchise Services, Inc.

 

 

 

 

 

With respect to members of the BHE Sub-Group, Berkshire Hathaway Energy Co. (BHE) requires all subsidiaries to pay to or receive from BHE an amount of tax based primarily on

 

the stand-alone method of allocation. The computation includes all tax benefits from tax deductions stemming from cost borne by utility customers.

BHE Sub-Group Continued:

 

 

 

Intero Real Estate Holdings, Inc.

Midwest Capital Group, Inc

Referral Network of IL LLC

 

Intero Real Estate Services, Inc.

Midwest Power Midcontinent Transmission Development, LLC

Referral Network of NY/NJ, LLC

 

Intero Referral Services, Inc.

Midwest Power Transmission Arkansas LLC

Relocation Advantage Partners, LLC

 

Interwest Mining Company

Midwest Power Transmission Iowa LLC

RGS Settlements of Pennsylvania, LLC

 

Iowa Realty Company, Inc

Midwest Power Transmission Kansas, LLC

RGS Title of Baltimore, LLC

 

Iowa Realty Insurance Agency, Inc

Midwest Power Transmission Oklahoma, LLC

RGS Title, LLC

 

Iowa Title Company

Midwest Power Transmission Texas, LLC

RHL Referral Company, LLC

 

JBRC, Inc

Midwest Preferred Realty, Inc

Roberts Brothers, Inc

 

Jim Huff Realty, Inc.

Midwest Realty Ventures, LLC

Roy H. Long Realty Company, Inc

 

JRHBW Realty, Inc d/b/a/ RealtySouth

MPT Heartland Development, LLC

S.W. Hydro, Inc.

 

Jumbo Road Holdings, LLC

MTL Canyon Holdings LLC

Sage Title Group, LLC

 

Kansas City Title, Inc

Nebraska Land Title & Abstract Company

Salton Sea Brine Processing Company

 

Kanstar Transmission, LLC

Nebraska Referral, Inc.

Salton Sea Funding Corporation

 

Kentucky Residential Referral Service, LLC

Nevada Power Company dba NV Energy

Salton Sea Minerals Corporation

 

Kentwood City Properties, LLC

Niguel Energy Company

Salton Sea Power Company

 

Kentwood Commercial, LLC

NNGC Acquisition LLC

Salton Sea Power Generation Company

 

Kentwood DTC, LLC

Norcon Holdings, Inc

Salton Sea Power LLC

 

Kentwood Real Estate Services, LLC

Northeast Referral Group,LLC

Salton Sea Royalty Company

 

Kentwood, LLC

Northern Consolidated Power, Inc

San Felipe Energy Company

 

Kern River Gas Transmission Company

Northern Natural Gas Company

Santa Rita Wind Energy LLC

 

Keystone Partners, LLC

NRS Referral Services, LLC

Saranac Energy Company, Inc

 

KR Holding, LLC

NV Energy, Inc.

SCS Realty Investment Group, LLC

 

L&F/Fonville Morisey Real Estate, LLC

NVE Holdings, LLC

SECI Holdings, Inc

 

L&F/Fonville Morisey Title, LLC

NVE Insurance Co, Inc.

Settlement Professionals, LLC

 

Lands of Sierra, Inc.

NW Referral Services, LLC

Sierra Gas Holding Company

 

Larabee School of Real Estate, Inc

O.E. Merger Sub II, LLC

Sierra Pacific Power Company dba NV Energy

 

LFFS, Inc.

O.E. Merger Sub III, LLC

Silvermine Ventures LLC

 

Long & Foster Closing Services, LLC

O.E. Merger Sub Inc.

Solar San Antonio LLC

 

Long & Foster Institute of Real Estate, Inc.

Pacific Minerals, Inc

Solar Star 3, LLC

 

Long & Foster Insurance Agency, Inc.

PacifiCorp

Solar Star 4, LLC

 

Long & Foster Licensing Company, Inc.

PCG Agencies, Inc.

Solar Star California XIX, LLC

 

Long & Foster Mortgage Ventures, Inc.

PCRE, L.L.C.

Solar Star California XX, LLC

 

Long & Foster Real Estate Ventures, Inc.

Pickford Escrow Company, Inc

Solar Star Funding, LLC

 

Long & Foster Real Estate, Inc.

Pickford Holdings, LLC

Solar Star Projects Holdings, LLC

 

Long & Foster Settlement Services, LLC

Pickford Real Estate, Inc

Southwest Relocation, LLC

 

Lovejoy Realty Inc.

Pickford Services Company, Inc

SSC XIX, LLC

 

Lovejoy Referral Network, LLC

Pilot Butte, LLC

SSC XX, LLC

 

M & M Ranch Acquisition Company LLC

Pinyon Pines Funding, LLC

The Escrow Firm

 

M & M Ranch Holding Company LLC

Pinyon Pines I Holding Company, LLC

The Kentwood Company at Cherry Creek, LLC

 

Magma Land Company I

Pinyon Pines II Holding Company, LLC

The Long & Foster Companies, Inc.

 

Magma Power Company

Pinyon Pines Projects Holding, LLC

The Referral Company

 

Marshall Wind Energy Holdings, LLC

Pinyon Pines Wind I, LLC

Thoroughbred Title Services, LLC

 

Marshall Wind Energy, LLC

Pinyon Pines Wind II, LLC

TIAC LLC

 

MEC Construction Services Company

PNW Referral, LLC

TitleSouth, LLC

 

MEHC Investment, Inc

PPW Holdings LLC

TLTC LLC

 

MEHC Merger Sub Inc

Preferred Carolinas Realty, Inc

Topaz Solar Farms, LLC

 

Merlin Realty Technologies, LLC

Preferred Carolinas Title Agency, LLC

TPZ Holding, LLC

 

MES Holding, LLC

Premier Service Abstract, LLC

Trapper Mining, Inc.

 

Metro Referral Associates, Inc.

Priority Title Corporation

TRMC LLC

 

MHC Investment Company

Professional Referral Organization, Inc

Two Rivers, Inc

 

MHC, Inc

Pru-One, Inc.

TX Jumbo Road Wind, LLC

 

Mid-America Referral Network, Inc.

Quad Cities Energy Company

VPC Geothermal LLC

 

MidAmerican Central California Transco LLC

Real Estate Knowledge Services, L.L.C.

Vulcan Power Company

 

MidAmerican Energy Company

Real Estate Links, LLC

Vulcan/BN Geothermal Power Company

 

MidAmerican Energy Machining Services LLC

Real Estate Referral Network, Inc

Wailuku Holding Company LLC

 

MidAmerican Energy Services, LLC

Reece & Nichols Alliance, Inc

Wailuku Investment LLC

 

MidAmerican Funding, LLC

Reece & Nichols Insurance, LLC

Wailuku River Hydroelectric Power Co, Inc.

 

MidAmerican Geothermal Development Corp

Reece & Nichols Realtors, Inc

Walker Jackson Mortgage Corporation

 

MidAmerican Wind Tax Equity Holdings, LLC

Reece Commercial, Inc.

Walnut Ridge Wind, LLC

 

Midland Escrow Services, Inc

Referral Associates of Georgia, LLC

Weathervane Referral Network, Inc.

 

Mid-States Title Insurance Agency, Inc.

Referral Network of Gloria Nilson, LLC

 

 

 

 

 

 

With respect to members of the BHE Sub-Group, Berkshire Hathaway Energy Co. (BHE) requires all subsidiaries to pay to or receive from BHE an amount of tax based primarily on

 

the stand-alone method of allocation. The computation includes all tax benefits from tax deductions stemming from cost borne by utility customers.

All Other Affiliates:

 

 

 

121 Acquisition Co., LLC

Berkshire Hathaway Finance Corporation

CMH Capital, Inc.

 

21 SPC, Inc.

Berkshire Hathaway Global Insurance Services, LLC

CMH Hodgenville, Inc.

 

21st Communities, Inc.

Berkshire Hathaway Homestate Insurance Company

CMH Homes, Inc.

 

21st Mortgage Corporation

Berkshire Hathaway Inc.

CMH Manufacturing West, Inc.

 

2K Polymer Systems, Inc.

Berkshire Hathaway Life Insurance Company of Nebraska

CMH Manufacturing, Inc.

 

3Wire Group Inc.

Berkshire Hathaway Specialty Concierge, LLC

CMH of KY, Inc.

 

A.E. COMPANY, INC.

Berkshire Hathaway Specialty Insurance Company

CMH Services, Inc.

 

AAA AIRCRAFT SUPPLY

Berkshire Indemnity Group Inc.

CMH Set and Finish, Inc.

 

ACCRA MANUFACTURING INC

BH Columbia Inc.

CMH Transport, Inc.

 

Accurate Installations, Inc.

BH Credit LLC

Coil Master Corporation

 

Acme Brick Company

BH Finance, Inc.

Columbia Insurance Company

 

Acme Building Brands, Inc

BH Holding LLC

Combined Claims Services, Inc.

 

Acme Management Company

BH Media Group, Inc.

Commercial Casualty Insurance Company

 

Acme Ochs Brick and Stone, Inc.

BH Shoe Holdings, Inc.

Commercial General Indemnity, Inc.

 

Acme Services Company, LLC

BHA Minority Interest Holdco, Inc.

COMPASS AEROSPACE NORTHWEST INC

 

Adalet/Scott Fetzer Company

BHG Life Insurance Company

Complementary Coatings Corporation

 

AEG Processing Center No. 35, Inc.

BHG Structured Settlements, Inc.

Composites Horizons LLC

 

AEG Processing Center No. 58, Inc.

BHSF, Inc.

Consumer Value Products, Inc.

 

AEROCRAFT HEAT TREATING CO INC

biBERK Insurance Services, Inc.

Continental Divide Insurance Company

 

AEROSPACE DYNAMICS INTERNATIONAL INC

Blue Chip Stamps, Inc.

Continental Indemnity Company

 

Affiliated Agency Operations Co.

BN Leasing Corporation

Cornelius Inc.

 

Affordable Housing Partners, Inc.

BNSF Communications, Inc.

Cornelius Renew, Inc.

 

AIPCF V CHI Blocker Inc

BNSF Logistics International, Inc.

Cort Business Services Corporation

 

AJF Warehouse Distributors, Inc.

BNSF Logistics Ocean Line, Inc.

Coverage Dynamics Group, Inc.

 

Albacor Shipping (USA) Inc.

BNSF Logistics, LLC

Criterion Insurance Agency

 

Albecca, Inc.

BNSF Railway Company

Crowd Supply, Inc.

 

Alexander Road Insurance Agency, Inc.

BNSF Railway International Services, Inc.

CSI Life Insurance Company

 

Alpha Cargo Motor Express, Inc

BNSF Spectrum, Inc.

CTB Credit Corp

 

Alu-Forge, Inc

Boat America Corporation

CTB Inc.

 

Ambucor Health Solutions, Inc.

Boat Owners Association of the United States

CTB International Corp

 

American All Risk Insurance Services Inc.

Boat/U.S, Inc.

CTB IW INC

 

American Commercial Claims Administrators Inc

Borsheim Jewelry Company, Inc

CTB Midwest Inc

 

American Dairy Queen Corporation

BR Agency, Inc.

CTB MN Investments

 

American Employers Group, Inc.

Brainy Toys, Inc.

CTB Technology Holding Inc.

 

AmGUARD Insurance Company

Brilliant National Services, Inc.

CTMS North America, Inc.

 

Andrews Laser Works Corporation

BRITTAIN MACHINE INC

Cubic Designs, Inc.

 

Angelo Po America, Inc.

Brooks Sports, Inc.

Cumberland Asset Management, Inc.

 

Applied Group Insurance Holdings, Inc.

Brookwood Insurance Company

Cypress Insurance Company

 

Applied Investigations Inc.

BuilderMT, Inc.

D.I. Properties Inc.

 

Applied Logistics, Inc.

Burlington Northern Railroad Holdings, Inc.

Dairy Queen Corporate Stores, Inc.

 

Applied Premium Finance, Inc.

Burlington Northern Santa Fe, LLC

DaVita, Inc.

 

Applied Processing Center No. 60, Inc.

Business Wire, Inc.

DCI Marketing Inc.

 

Applied Risk Services of New York, Inc.

C Flow, Inc.

Denver Brick Company

 

Applied Risk Services, Inc.

CALEDONIAN ALLOYS INC

DESIGNED METAL CONNECTIONS, INC.

 

Applied Underwriters Captive Risk Assurance Company, Inc.

California Insurance Company

DICKSON TESTING CO INC

 

Applied Underwriters, Inc.

Camp Manufacturing Company

Display Technologies LLC

 

ARCTURUS MANUFACTURING CORPORATION

Cannon Equipment LLC

DIY Technologies, Inc.

 

Artform International Inc.

CANNON MUSKEGON CORPORATION

DL Trading Holdings I, Inc.

 

Atlanta International Insurance Company

Carefree/Scott Fetzer Company

DQ Funding Corporation

 

ATLANTIC PRECISION INC

CARLTON FORGE WORKS

DQF, Inc.

 

AU Captive Risk Assurance Co.

Cavalier Homes, Inc.

DQGC, Inc.

 

AU Holding Company, Inc.

CCC Lonestar LLC

DragonFly Aeronautics LLC

 

AVIBANK MANUFACTURING INC

Central States Indemnity Co. of Omaha

DTTF, Inc.

 

AzGUARD Insurance Company

Central States of Omaha Companies, Inc.

Duracell Distributing Inc.

 

Bayport Systems, Inc.

Charter Brokerage Holdings Corp.

Duracell Industrial Operations, Inc.

 

BDT I-A Plum Corp.

Chemtool Incorporated

Duracell Manufacturing Co.

 

Ben Bridge Jeweler, Inc.

CJE II

Duracell U.S. Operations Inc

 

Benjamin Moore & Co.

Claims Services, Inc.

EastGUARD Insurance Company

 

Benson Industries, Inc.

Clayton Commercial Buildings, Inc.

Eco Color Company

 

Benson, Ltd.

Clayton Education Corp.

Ecodyne Corporation

 

Berkshire Hathaway Assurance Corporation

Clayton Homes, Inc.

Ellis & Watts Global Industries, Inc.

 

Berkshire Hathaway Automotive Inc.

Clayton Properties Group II, Inc.

Elm Street Corporation

 

Berkshire Hathaway Credit Corporation

Clayton Properties Group, Inc.

Empire Distributors of Colorado, Inc.

 

Berkshire Hathaway Direct Insurance Company

Clayton, Inc.

Empire Distributors of North Carolina, Inc.

All Other Affiliates Continued:

 

 

 

Empire Distributors of Tennessee, Inc.

GRD Holdings Corporation

Lubrizol Global Management, Inc.

 

Empire Distributors, Inc.

GREENVILLE METALS INC

Lubrizol Inter-Americas Corporation

 

ENVIRONMENT ONE CORPORATION

GUARDco, Inc.

Lubrizol International Management Corporation

 

EXACTA AEROSPACE INC

H. H. Brown Shoe Company, Inc.

Lubrizol Oilfield Solutions, Inc.

 

Executive Jet Management, Inc.

H.J. Justin & Sons, Inc.

Lubrizol Overseas Trading Corporation

 

Exsif Worldwide, Inc.

HACKNEY LADISH INC

M & C Products, Inc.

 

ExtruMed, Inc.

Halex/Scott Fetzer Company

M&M Manufacturing, Inc.

 

FATIGUE TECHNOLOGY INC

HAMILTON AVIATION INC

Mapletree Transportation, Inc.

 

Financial Services Plus, Inc.

Hawthorn Life International, Ltd.

Marathon Suspension Systems, Inc.

 

Finial Holdings, Inc.

HeatPipe Technology, Inc.

Marmon Beverage Technologies, Inc.

 

Finial Reinsurance Company

HELICOMB INTERNATIONAL INC

Marmon Crane Services, Inc.

 

First Berkshire Hathaway Life Insurance Company

Helzberg's Diamond Shops, Inc.

Marmon Distribution Services, Inc.

 

FlightSafety Capital Corp.

Henley Holdings, LLC

Marmon Energy Services Company

 

FlightSafety Development Corp.

HG-Power Plant, Inc.

Marmon Engineered Components Company

 

FlightSafety International Inc.

Hohmann & Barnard, Inc.

Marmon Foodservice Technologies LLC

 

FlightSafety International Middle East Inc.

Home Trust Company

Marmon Holdings, Inc.

 

FlightSafety New York, Inc.

Homefirst Agency, Inc.

Marmon Retail & Highway Technologies Company LLC

 

FlightSafety Properties, Inc.

Homemakers Plaza, Inc.

Marmon Retail Products, Inc.

 

FlightSafety Services Corporation

HOWELL PENNCRAFT, INC.

Marmon Retail Store Equipment LLC

 

Floors, Inc.

HUM Marketing Group, Inc.

Marmon Retail Technologies Company

 

Focused Technology Solutions, Inc.

HUNTINGTON ALLOYS CORPORATION

Marmon Tubing, Fittings & Wire Products, Inc.

 

Fontaine Commercial Trailer, Inc.

IdeaLife Insurance Company

Marmon Water, Inc.

 

Fontaine Engineered Products, Inc.

Illinois Insurance Company

Marmon Wire & Cable, Inc.

 

Fontaine Fifth Wheel Company

Ingersoll Cutting Tool Company

Marmon-Herrington Company

 

Fontaine Modification Company

Innovative Building Products, Inc

Marquis Jet Holdings, Inc.

 

Fontaine Spray Suppression Company

Innovative Coatings Technology Corporation

Marquis Jet Partners, Inc.

 

Fontaine Trailer Company LLC

Interco Tobacco Retailers, Inc.

Maryland Ventures, Inc..

 

Forest River Holdings, Inc.

International Dairy Queen, Inc.

McCarty-Hull Cigar Company, Inc.

 

Forest River Manufacturing LLC

International Insurance Underwriters, Inc.

McLane Beverage Distribution, Inc.

 

Forest River, Inc.

Intrepid JSB, Inc.

McLane Beverage Holding, Inc.

 

Freedom Warehouse Corp.

Ironwood Plastics Inc

McLane Company, Inc.

 

Fruit of the Loom Direct, Inc.

Iscar Metals Inc.

McLane Eastern, Inc.

 

Fruit of the Loom Trading Company

ITTI Group USA Holdings, Inc.

McLane Express, Inc.

 

Fruit of the Loom, Inc.

ITTI Investment Holdings, Inc.

McLane Foods, Inc.

 

Fruit of the Loom, Inc. (Sub)

J&L FIBER SERVICES INC

McLane Foodservice Distribution, Inc.

 

FTI MANUFACTURING INC

J.L. Mining Company

McLane Foodservice, Inc.

 

FTL Regional Sales Co., Inc.

Johns Manville China, Ltd.

McLane Mid-Atlantic, Inc.

 

Garan Central America Corp.

Johns Manville Corporation

McLane Midwest, Inc.

 

Garan Incorporated

Johns Manville, Inc.

McLane Minnesota, Inc.

 

Garan Manufacturing Corp.

Jordan's Furniture, Inc.

McLane Network Solutions, Inc.

 

Garan Services Corp

Justin Brands, Inc.

McLane New Jersey, Inc.

 

Gateway Underwriters Agency, Inc.

Kahn Ventures, Inc.

McLane Ohio, Inc.

 

GEICO Advantage Insurance Company

Karmelkorn Shoppes, Inc.

McLane Southern, Inc.

 

GEICO Casualty Co.

KEN'S SPRAY EQUIPMENT, INC.

McLane Suneast, Inc.

 

GEICO Choice Insurance Company

Kinexo, Inc.

McLane Tri-States, Inc.

 

GEICO Corporation

KITCO Fiber Optics, Inc.

McLane Western, Inc.

 

GEICO General Insurance Co.

KLUNE HOLDINGS INC

MCWILLIAMS FORGE COMPANY

 

GEICO Indemnity Co.

KLUNE INDUSTRIES INC

Medical Protective Finance Corporation

 

GEICO Insurance Agency

Kova Solutions, Inc.

MedPro Group, Inc

 

GEICO Marine Insurance Company

L.A. Terminals, Inc.

MedPro Risk Retention Services, Inc.

 

GEICO Products, Inc.

LeachGarner, Inc.

Merit Distribution Services, Inc.

 

GEICO Secure Insurance Company

Lipotec USA, Inc.

METALAC FASTENERS INC

 

Gen Re Intermediaries Corporation

LiquidPower Specialty Products, Inc.

Meyn LLC

 

General Re Corporation

LJ AERO HOLDINGS INC

MFS Fleet, Inc.

 

General Re Financial Products Corporation

LJ SYNCH HOLDINGS INC

Midwest Northwest Properties, Inc.

 

General Re Life Corporation

LMG Ventures, LLC

Miller-Sage, Inc.

 

General Reinsurance Corporation

Lockwood Street Urban Renewal Corporation

Mindware Corporation

 

General Star Indemnity Company

Los Angeles Junction Railway Company

MiTek Holdings, Inc.

 

General Star Management Company

LSP Holding, Inc.

MiTek Industries, Inc.

 

General Star National Insurance Company

LSPI Holdings Inc.

MiTek USA, Inc.

 

Genesis Insurance Company

Lubricant Investments, Inc.

MLMIC Insurance Company

 

Genesis Management and Insurance Services Corporation

Lubrizol Advanced Materials China, Inc.

MLMIC Services, Inc.

 

Government Employees Financial Corp.

Lubrizol Advanced Materials Holding Corporation

Montana Retail Properties, Inc.

 

Government Employees Insurance Co.

Lubrizol Advanced Materials, Inc.

Morgantown-National Supply, Inc.

All Other Affiliates Continued:

 

 

 

Mount Vernon Fire Insurance Company

PRIMUS INTERNATIONAL INC

SOS METALS, INC.

 

Mount Vernon Specialty Insurance Company

Princeton Advertising & Marketing Group, Inc.

Southern Energy Homes, Inc.

 

Mouser Electronics, Inc.

Princeton Insurance Company

SOUTHWEST UNITED INDUSTRIES INC

 

Mouser JV 1, Inc

Princeton Risk Protection, Inc.

SPECIAL METALS CORPORATION

 

MPP Co., Inc.

Priority One Financial Services, Inc.

SPECIALIZED PIPE SERVICES, INC.

 

MPP Pipeline Corporation

PRISM Holdings LLC

Spectra Contract Flooring Puerto Rico, Inc.

 

MS Property Company

PRISM Plastics, Inc.

SPS INTERNATIONAL INVESTMENT COMPANY

 

MW Wholesale, Inc.

Pro Installations, Inc.

SPS TECHNOLOGIES LLC

 

National Fire & Marine Insurance Company

Procrane Holdings, Inc.

SPS Technologies Mexico LLC

 

National Indemnity Company

PROGRESSIVE INCORPORATED

SSP-SiMatrix Inc.

 

National Indemnity Company of Mid-America

Promesa Health, Inc.

Stahl/Scott Fetzer Company

 

National Indemnity Company of the South

PROTECTIVE COATING INC

Star Furniture Company

 

National Liability & Fire Insurance Company

QS Partners LLC

Star Lake Railroad Company

 

Nationwide Uniforms

R.C. Willey Home Furnishings

Strategic Staff Management, Inc.

 

Nebraska Furniture Mart, Inc.

Radnor Specialty Insurance Company

STRATOFLIGHT

 

NetJets Aviation, Inc.

Railserve, Inc.

Summit Distribution Services, Inc.

 

NetJets Europe Holdings, LLC

Railsplitter Holdings Corporation

SXP CRA-OCTG Inc.

 

NetJets Inc.

RATHGIBSON HOLDING CO LLC

TBS USA, Inc.

 

NetJets International, Inc.

RCP Investment, Inc.

TEXAS HONING INC

 

NetJets Sales, Inc.

Redwood Fire and Casualty Insurance Company

Texas Insurance Company

 

NetJets Services, Inc.

RENTCO Trailer Corporation

The Ben Bridge Corporation

 

NetJets U.S., Inc.

Resolute Management Inc.

The Buffalo News, Inc.

 

New England Asset Management, Inc.

RFMW, Ltd.

The BVD Licensing Corporation

 

NFM of Kansas, Inc.

Richline Group, Inc

The Duracell Company

 

NFM SERVICES, LLC

Ringwalt & Liesche Co.

The Fechheimer Brothers Co.

 

NJE Holdings, LLC

Rio Grande, Inc.

The Indecor Group, Inc.

 

NJI Sales, Inc.

Roxell USA, Inc.

The Lubrizol Corporation

 

Noranco Manufacturing (USA) Ltd.

Rush Air Inc

The Medical Protective Company

 

NorGUARD Insurance Company

Sager Electrical Supply Co. Inc

The Pampered Chef, Ltd.

 

North American Casualty Co.

Sales Simplicity Software, Inc.

The Scott Fetzer Company

 

Northern States Agency, Inc.

Santa Fe Pacific Insurance Company

The Wilkins Corporation

 

Noveon Hilton Davis, Inc.

Santa Fe Pacific Pipeline Holdings, Inc.

The Zia Company

 

NSS TECHNOLOGIES INC

Santa Fe Pacific Pipelines, Inc.

THI ACQUISITION INC

 

Oak River Insurance Company

Santa Fe Pacific Railroad Company

TIMET ASIA INC

 

Old United Casualty Company

SchILL Loans, Inc.

TIMET REAL ESTATE CORPORATION

 

Orange Julius Of America

Schulz Investment Corporation

TITANIUM METALS CORPORATION

 

Oriental Trading Company, Inc.

SCHULZ U.S.A. INC.

TMCA INTERNATIONAL INC

 

OTC Brands, Inc.

Scott Fetzer Financial Group, Inc.

TMI Climate Solutions, Inc.

 

OTC Direct, Inc.

ScottCare Corporation

Tool-Flo Manufacturing, Inc.

 

OTC Worldwide Holdings, Inc.

See's Candies, Inc.

Top Five Club, Inc.

 

Particle Sciences, Inc.

See's Candy Shops, Incorporated

Total Quality Apparel Resources

 

PCC FLOW TECHNOLOGIES HOLDINGS INC

Serpentec, Inc.

TPC European Holdings, LTD.

 

PCC FLOW TECHNOLOGIES INC.

Seventeenth Street Realty, Inc.

TPC North America, Ltd.

 

PCC ROLLMET INC

SFEG Corp.

Transco, Inc.

 

PCC STRUCTURALS INC

Shaw Contract Flooring Services, Inc.

Transportation Technology Services, Inc.

 

Penn Coal Land, Inc.

Shaw Diversified Services, Inc.

TRH Holding Corp.

 

Pennsylvania Insurance Company

Shaw Floors, Inc.

Triangle Suspension Systems, Inc.

 

Perfection Hy-Test Company

Shaw Funding Company

Tricycle, Inc.

 

PERMASWAGE HOLDINGS, INC.

Shaw Industries Group, Inc.

TSE Brakes, Inc.

 

Pine Canyon Land Company

Shaw Industries, Inc.

TTI, Inc.

 

PLASMA COATING CORPORATION

Shaw International Services, Inc.

Tucker Safety Products, Inc.

 

Plaza Financial Services Co.

Shaw Retail Properties, Inc.

TXFM, Inc.

 

Plaza Resources Co.

Shaw Sports Turf California, Inc.

U.S. Investment Corporation

 

PLICO

Shaw Transport, Inc.

U.S. Underwriters Insurance Co.

 

PLICO Financial, Inc

Shultz Steel Company

UCFS Europe Company

 

Polysols Holdings, Inc.

SHX Flooring, Inc.

Unified Supply Chain, Inc.

 

Polysols Textile Solutions, Inc.

SidePlate Systems, Inc.

Uni-Form Components Co.

 

Precision Brand Products, Inc.

Smilemakers Canada Inc.

Union Sales, Inc.

 

PRECISION CASTPARTS CORP

Smilemakers, Inc.

Union Tank Car Company

 

PRECISION FOUNDERS INC

SN Management, Inc.

Union Underwear Co., Inc

 

Precision Steel Warehouse - Charlotte

Snappy ADP, Inc.

United Consumer Financial Services Company

 

Precision Steel Warehouse, Inc.

Soco West, Inc.

United Direct Finance, Inc.

 

Press Forge Company

Sonnax Transmission Company

United States Aviation Underwriters, Incorporated

 

PRIMUS INTERNATIONAL HOLDING COMPANY

SOS METALS SAN DIEGO, LLC

United States Liability Insurance Company

All Other Affiliates Continued:

 

 

 

UNIVERSITY SWAGING CORPORATION

 

 

 

UTLX Company

 

 

 

Van Enterprises, Inc.

 

 

 

Vanderbilt ABS Corp.

 

 

 

Vanderbilt Mortgage and Finance, Inc.

 

 

 

Vanity Fair, Inc.

 

 

 

Velocity Freight Transport, Inc.

 

 

 

Veritas Insurance Group, Inc.

 

 

 

Vesta Funding, Inc.

 

 

 

Vesta Intermediate Funding, Inc.

 

 

 

VFI-Mexico, Inc.

 

 

 

Visilinx, Inc.

 

 

 

Vision Retailing, Inc.

 

 

 

VT Insurance Acquisition Sub Inc.

 

 

 

Warwick Chemicals USA, Inc.

 

 

 

Wayne/Scott Fetzer Company

 

 

 

WEAVER MANUFACTURING INC

 

 

 

Webb Wheel Products, Inc.

 

 

 

Western Builders Supply, Inc.

 

 

 

Western Fruit Express Company

 

 

 

Western/Scott Fetzer Company

 

 

 

WestGUARD Insurance Company

 

 

 

Whittaker, Clark & Daniels, Inc.

 

 

 

WMC Corp.

 

 

 

World Book Encyclopedia, Inc.

 

 

 

World Book, Inc.

 

 

 

World Book/Scott Fetzer Company

 

 

 

World Investments, Inc.

 

 

 

Worldwide Containers, Inc.

 

 

 

WPLG, Inc.

 

 

 

Wrightsoft Corporation

 

 

 

WYMAN GORDON COMPANY

 

 

 

WYMAN GORDON FORGINGS CLEVELAND INC

 

 

 

WYMAN GORDON FORGINGS INC

 

 

 

WYMAN GORDON INVESTMENT CASTINGS INC

 

 

 

WYMAN GORDON PENNSYLVANIA LLC

 

 

 

X-L-Co., Inc.

 

 

 

XTRA Companies, Inc.

 

 

 

XTRA Corporation

 

 

 

XTRA Finance Corporation

 

 

 

XTRA Intermodal, Inc.

 


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Federal:
2
Excise
3
Income
2,718,898
283,979,351
451,900,237
29,127,676
141,512,108
287,548,281
3,568,930
4
Payroll
210,799
14,518,168
23,713,166
9,262,733
278,534
9,482,976
5,035,192
5
Miscellaneous
569
2,016,626
2,003,980
12,077
19,961
2,033,660
6
Total
2,929,128
267,444,557
428,187,071
21,868,923
141,802,719
278,045,344
10,637,782
7
Iowa:
8
Franchise
7,992,072
41,063,051
40,141,314
820
8,914,629
9
Fuel
10
Miscellaneous
22,940
5,878
7,134
24,197
11
Income
1,621,928
13,525,037
41,960,185
12,884,194
13,929,026
17,352,742
3,827,705
12
Payroll
22,789
92,991
101,211
10,254
24,823
65,295
27,696
13
Property
111,204,473
112,886,397
108,200,235
11,377
115,879,259
104,600,854
8,210,842
14
Occupation
538,064
538,064
15
Use/Sales
4,494,341
161
3,962,544
8,457,046
16
Total
122,114,687
140,517,563
103,063,973
12,877,363
146,690,916
87,313,407
12,066,243
17
Illinois:
18
Property
3,054,369
5,656,412
4,343,523
814
4,368,072
5,599,183
57,229
19
Use/Misc.
61,127
71,199
132,326
20
Unemployment
13,641
36,788
39,668
16,521
21
ICC Public Utility Fund
22
Invested Capital
2,465,004
1,908,112
268,614
288,278
992,507
1,472,497
23
Public Utility
1,915,006
1,859,669
55,337
24
Income
4,449,642
1,417,440
839,807
4,504,028
2,202,861
1,309,853
107,587
25
Total
7,578,779
11,525,061
7,440,611
4,732,160
6,931,069
7,901,543
1,637,313
26
Minnesota:
27
Excise
28
Income
29
Payroll
30
Property
31
Regulatory
32
Use/Sales
33
Total
34
Nebraska:
35
Income
91,984
192,360
43,558
68,829
259,073
111,179
81,181
36
Payroll
470,866
158,399
629,265
37
Franchise
16,333
117,286
114,528
19,091
38
Property
101,900
108,686
103,986
106,600
108,686
39
Use / Sales
40
Total
681,083
418,332
174,956
89,570
1,014,029
111,179
189,867
41
South Dakota:
42
Fuel
47,063
47,063
43
Property
1,106,808
1,138,535
1,103,736
1,141,607
120,810
1,017,725
44
Income
693,968
693,968
45
Regulatory
104,802
148,958
131,793
121,967
46
Use/Sales
5,669
33
356
6,058
47
Excise
112
16,934
17,662
616
48
Payroll
25,924
14,102
17,949
29,771
49
Total
1,937,283
1,351,523
1,314,000
676,019
1,298,787
120,810
1,017,725
50
Missouri:
51
Income
62,791
181,894
196,410
48,275
165,746
16,148
52
Use/Sales
53
Property
128,560
74,701
203,261
74,701
54
Total
65,769
181,894
74,701
196,410
154,986
240,447
16,148
55
Kansas:
56
Income
17,716
306,596
215,027
109,285
132,638
173,958
57
Payroll
58
Property
247,721
469,988
482,713
234,996
469,988
59
Total
265,437
776,584
482,713
215,027
344,281
132,638
643,946
60
Other States:
61
Income
3,819,019
45,399
120,798
3,199,062
453,760
508,907
463,508
62
Assessment
63
Use/Sales
64
Property
80,019
644,679
96,378
628,320
65
Total
3,739,000
690,078
120,798
3,102,684
174,560
508,907
463,508
40
TOTAL
131,701,628
298,101,375


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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%
22,811
3,469
19,342
6 Years
3
4%
220,857
21,862
198,995
12 Years
4
10%
17,666,878
979,382
16,687,496
19 Years
5
8%
1,682,397
98,612
1,583,785
17 Years
8 TOTAL
19,592,943
1,103,325
18,489,618
9
Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10
3%
11
4%
43,607
4,041
39,566
10 Years
12
8%
255,731
11,626
244,105
21 Years
13
10%
2,300,923
125,316
2,175,607
18 Years
14
TOTAL
2,600,261
140,983
2,459,278
48 TOTAL


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
WS3 Operating Fund
108,421
33,293,041
33,184,620
2
CIAC Tax Gross-up Electric
5,717,694
1,715,748
1,701,048
5,702,994
3
CIAC Tax Gross-up Gas
2,981,232
648,046
1,070,093
3,403,279
4
MGP Iowa Remediation Sites
6,867,000
376,800
6,360,800
12,851,000
5
Neal 3 Working Fund
33,451,361
33,874,336
422,975
6
Neal 4 Operating Fund
2,253,827
59,134,672
57,312,254
431,409
7
Transmission Collateral
12,766
12,766
8
Louisa working funds
371,914
17,445,683
17,129,665
55,896
9
Misc Deferred Credits
82,500
82,500
10
WS4 Operating Fund
1,873,005
48,117,137
46,919,048
674,916
11
Unearned Income AE Dairy
92,088
49,774
30,649
72,963
12
Renewable Advantage Program
242,756
583
45,822
287,995
13
DF CR-EE Equity - Elec
2,144,144
859,001
2,412,231
3,697,374
14
DF CR-EE Equity - Gas
1,872,606
863,694
676,999
1,685,911
15
DF CR -Distribution
8,265
39,717
200,002
168,550
16
DF-CR -Allow and RECS
5,843,849
285,771
95,042
5,653,120
17
DF-CR -Siemens LT Svc Agreement
26,825,309
5,112,977
6,169,328
27,881,660
18
DF CR-Misc Retainage
3,026,714
3,403,890
2,218,025
1,840,849
19
DF CR 2018 MMAG Conference
55,693
169,582
116,565
2,676
20
DF CR Long-term Trading Collateral
50,000
250,000
300,000
47
TOTAL
60,347,283
204,967,477
209,849,027
65,228,833


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
68,514,426
10,090,068
7,688,940
70,915,554
5
Other
5.1
Other
5.2
Other
8
TOTAL Electric (Enter Total of lines 3 thru 7)
68,514,426
10,090,068
7,688,940
70,915,554
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
70,915,554
16.1
Other
16.2
Other
17
TOTAL (Acct 281) (Total of 8, 15 and 16)
68,514,426
10,090,068
7,688,940
70,915,554
18
Classification of TOTAL
19
Federal Income Tax
66,986,909
9,774,984
7,629,382
69,132,511
20
State Income Tax
1,527,518
315,084
59,558
1,783,044
21
Local Income Tax


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
2,693,556,793
674,596,129
618,322,858
5,427
4,464
282
236
2,749,831,027
3
Gas
203,570,861
14,714,524
7,581,480
282
236
210,703,905
4
Other (Specify)
5
Total (Total of lines 2 thru 4)
2,897,127,654
689,310,653
625,904,338
5,427
4,464
2,960,534,932
6
Other - Net ASC 740 Adjustment
(a)
446,611,474
4,927,727,210
4,949,812,214
424,526,470
9
TOTAL Account 282 (Total of Lines 5 thru 8)
2,450,516,180
689,310,653
625,904,338
5,427
4,464
4,927,727,210
4,949,812,214
(b)
2,536,008,462
10
Classification of TOTAL
11
Federal Income Tax
1,767,666,254
678,213,450
614,672,179
1,999
783
3,740,400,909
3,738,202,267
1,829,010,099
12
State Income Tax
682,849,926
11,097,203
11,232,159
3,428
3,681
1,187,326,301
1,211,609,947
706,998,363
13
Local Income Tax


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOtherProperty

The amounts shown for Other on row 6 are the amounts computed to adjust the regulatory deferreds included on rows 2 and 3 to the amounts required for SEC reporting under the rules of ASC 740.

 

These amounts arise out of “flow-through” treatment required by regulators in the company’s main state of operations for the federal and state impacts of basis differences, the impact on state taxes from accelerated depreciation, and the impact in all jurisdictions for pre-1981 vintages of flow-through of cost of removal and the use of guideline life SL depreciation for regulatory deferreds.

 

Amounts for jurisdiction rate making

 

 

 

 

 

 

 

Balance at Beginning of Year

(b)

Balance at End of Year

(k)

Electric

2,693,496,333

 

2,749,769,604

Gas

203,570,861

 

210,703,905

(b) Concept: AccumulatedDeferredIncomeTaxesOtherProperty

ADIT- 282

Total

Gas, Prod

Only

 

 

 

 

Or Other

Transmission

Plant

Labor

 

 

Related

Related

Related

Related

 

 

Retail

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

FAS109

424,526,471

424,526,471

 

 

 

Transmission Plant

(253,884,355)

 

(253,884,355)

 

 

General Plant

(75,907,724)

(14,203,465)

 

 

(61,704,259)

Other Plant

(2,630,681,430)

(2,630,681,430)

 

 

 

Plant Related BTL

(61,423)

(61,423)

 

 

 

 

 

 

 

 

 

Subtotal - p275

(2,536,008,461)

(2,220,419,847)

(253,884,355)

-

(61,704,259)

Less FASB 109 Above if not separately removed

424,526,471

424,526,471

 

-

 

Less FASB 106 Above if not separately removed

 

 

 

 

 

Total

(2,960,534,932)

(2,644,946,318)

(253,884,355)

-

(61,704,259)


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Other (Nonproperty Deferred
32,978,023
77,592,136
85,812,257
24,757,902
4
Other (Reg Asset & Liab DIT)
107,938,838
40,982,768
42,279,116
209,244
25,571
106,458,817
5
Other (ASC 740 Gross-up)
2
2
6
Other (ASC 740 Adj - Correct
1
2,716,511
2,228,428
488,084
7
Other (ASC 740 Adj Tax Posit
609,643
350,890
76,649
335,402
9 TOTAL Electric (Total of lines 3 thru 8)
140,307,217
121,642,305
130,396,450
209,244
25,571
131,369,399
10
Gas
11
Other (Nonproperty Deferred
25,971,773
78,897,186
91,101,964
13,766,995
12
Other (Reg Asset & Liab DIT)
8,510,018
9,738,192
12,867,163
80,527
9,841
5,310,361
13
Other (ASC 740 Gross-up)
1
1
14
Other (ASC 740 Adj - Correct
15
Other (ASC 740 Adj Tax Posit
41,096
14,804
3,891
30,183
17 TOTAL Gas (Total of lines 11 thru 16)
34,440,696
88,650,182
103,973,018
80,527
9,841
19,047,174
18 TOTAL Other
1,143,229
(c)
1,563,435,845
(d)
1,560,435,818
4,143,256
19 TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)
175,891,142
210,292,487
234,369,468
1,563,435,845
1,560,435,818
289,771
35,412
(e)
154,559,829
20
Classification of TOTAL
21
Federal Income Tax
119,767,117
141,251,912
154,926,520
1,029,544,236
1,026,548,720
168,248
22,891
108,942,668
22
State Income Tax
56,124,025
69,040,575
79,442,948
533,891,609
533,887,098
121,523
12,521
45,617,161
23
Local Income Tax
NOTES


FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxLiabilitiesOtherDescriptionOfDebitedAccountNumber

Accounts Credited:

 

190, 219, 236, 283

(b) Concept: AccumulatedDeferredIncomeTaxLiabilitiesOtherDescriptionOfCreditedAccountNumber

Accounts Debited:

 

165, 190, 219, 236

(c) Concept: AccumulatedDeferredIncomeTaxLiabilitiesOtherChangesDebitedToProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions

Other:

 

Below the Line Deferred Income Taxes $ 1,563,253,577

ASC 740 Adjustments - Corrections 166,191

ASC 740 Adjustments - Tax Positions 16,077

Total $ 1,563,435,845

(d) Concept: AccumulatedDeferredIncomeTaxLiabilitiesOtherChangesCreditedToProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions

Other:

 

Below the Line Deferred Income Taxes $ 1,560,262,817

ASC 740 Adjustments - Corrections 171,854

ASC 740 Adjustments - Tax Positions 1,147

Total $ 1,560,435,818

(e) Concept: AccumulatedDeferredIncomeTaxesOther

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

ADIT-283

Total

Gas, Prod

Only

 

 

 

 

Or Other

Transmission

Plant

Labor

 

 

Related

Related

Related

Related

 

 

Retail

 

 

 

 

 

 

 

 

 

Regulated

 

 

 

 

 

RA - ARO

(44,589,272)

(44,589,272)

 

-

 

ARO Asset

(42,292,308)

(42,292,308)

 

-

 

Billed PGA/EAC

(15,385,666)

(11,287,020)

 

(4,098,646)

 

Deferred Rate Case Expense

(38,812)

(17,307)

 

(21,505)

 

Demand Side Management

(9,400,343)

(9,400,343)

 

 

 

Electric Contracts Asset - NC

(10,333)

(10,333)

 

 

 

Emission Allowances

(257,093)

(257,093)

 

 

 

Gain/Loss on Reacquired Debt

(3,048,847)

(258,218)

 

(2,790,629)

 

State NOL Carryforwards

(7,596,655)

(1,011,971)

 

(6,584,685)

 

FIN 48

(122,497)

30,182

 

(152,679)

 

Prepaid Insurance

(834,502)

(71,336)

 

(763,167)

 

QC Station Writedown

(45,175)

(45,175)

 

 

 

RA - Gas Contracts

(167,827)

(167,827)

 

 

 

RA - Medicare Def Tax

(1,059,464)

(294,427)

 

 

(765,037)

RA - MFG Gas

(1,917,805)

(1,917,805)

 

 

 

RA - OPEB Liab

(10,553,168)

(2,954,887)

 

 

(7,598,281)

RA - Pension Liab

(1,657,568)

(464,119)

 

 

(1,193,449)

RA - QCS Nuclear Fuel

(939,327)

(939,327)

 

 

 

RA - SERP Liab

(5,103,927)

(1,429,100)

 

 

(3,674,827)

RA - Unrealized Loss - Derivative Hedge

(5,395,984)

(5,395,984)

 

 

 

 

 

 

 

 

 

Nonregulated

 

 

 

 

 

State NOL Carryforwards

(741,194)

(114,471)

 

(626,723)

 

Deferred Intercompany Gain

(3,014,351)

 

 

(3,014,351)

 

State Charitable Contribution Carryforward

(9,490)

(1,396)

 

(8,093)

 

FIN 48

(376,100)

(376,100)

 

 

 

Prior Year State Tax Pmts/Receipts

(2,121)

(2,121)

 

 

 

 

 

 

 

 

 

Subtotal - p277

(154,559,829)

(123,267,758)

-

(18,060,477)

(13,231,594)

Less FASB 109

-

-

 

-

 

Less FASB 106

-

 

 

 

 

Total

(154,559,829)

(123,267,758)

-

(18,060,477)

(13,231,594)


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Deferred tax ITC
8,887,120
1,190,562
421,134
8,117,692
2
Nuclear insurance QCS
5,820,400
6,600
5,827,000
3
QCS outage expense
9,417,475
7,759,800
7,219,500
8,877,175
4
Unrealized G/L on gas contracts
2,956,569
19,745,337
16,825,768
37,000
5
Provision IA revenue sharing
26,048,000
101,269,000
145,714,000
70,493,000
6
ARO regulatory liability
173,069,161
183,131,909
170,001,413
159,938,665
7
Pension funded status
41,187,546
41,709,073
521,527
8
DSM commercial and industrial construction incens
3,022,724
2,596,060
5,056,474
5,483,138
9
Prefunded debt AFUDC for MVP projects
8,738,803
213,534
314,284
8,839,553
10
Prefunded equity AFUDC for MVP projects
26,221,242
623,640
911,967
26,509,569
11
Deferred tax electric/gas
625,453,449
332,184,005
266,539,980
559,809,424
12
Uncertain tax positions electric/gas
46,771,232
20,131,010
7,185,742
33,825,964
13
Excess deferred income tax amort.- electric/gas
48,495,967
76,509,563
28,013,596
14
Deferred Income Tax - Medicare
4,403,307
609,732
3,793,575
41 TOTAL
977,593,721
763,453,204
697,837,684
911,978,201


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
(a)
695,918,807
657,163,867
(h)
6,763,028
6,207,289
(o)
669,574
661,776
3
CommercialAndIndustrialSalesAbstract
(442) Commercial and Industrial Sales
4
CommercialSalesAbstract
Small (or Comm.) (See Instr. 4)
(b)
315,425,838
308,069,908
(i)
3,957,079
3,812,882
(p)
93,930
92,233
5
IndustrialSalesAbstract
Large (or Ind.) (See Instr. 4)
(c)
758,342,410
703,969,504
(j)
13,595,275
12,964,048
(q)
1,813
1,817
6
PublicStreetAndHighwayLightingAbstract
(444) Public Street and Highway Lighting
(d)
15,129,803
15,685,292
66,802
80,811
487
484
7
OtherSalesToPublicAuthoritiesAbstract
(445) Other Sales to Public Authorities
(e)
105,215,311
101,282,776
(k)
1,523,124
1,478,617
(r)
13,913
13,935
8
SalesToRailroadsAndRailwaysAbstract
(446) Sales to Railroads and Railways
9
InterdepartmentalSalesAbstract
(448) Interdepartmental Sales
1,248,780
1,024,013
22,380
18,332
86
85
10
SalesToUltimateConsumersAbstract
TOTAL Sales to Ultimate Consumers
1,891,280,949
1,787,195,360
(l)(m)(n)
25,927,688
24,561,979
779,803
770,330
11
SalesForResaleAbstract
(447) Sales for Resale
286,571,592
214,601,862
11,180,851
9,165,323
5
5
12
SalesOfElectricityAbstract
TOTAL Sales of Electricity
2,177,852,541
2,001,797,222
37,108,539
33,727,302
779,808
770,335
13
ProvisionForRateRefundsAbstract
(Less) (449.1) Provision for Rate Refunds
1,996,000
2,759,590
14
RevenuesNetOfProvisionForRefundsAbstract
TOTAL Revenues Net of Prov. for Refunds
2,175,856,541
1,999,037,632
37,108,539
33,727,302
779,808
770,335
15
OtherOperatingRevenuesAbstract
Other Operating Revenues
16
ForfeitedDiscounts
(450) Forfeited Discounts
3,636,979
3,346,509
17
MiscellaneousServiceRevenues
(451) Miscellaneous Service Revenues
557,925
418,164
18
SalesOfWaterAndWaterPower
(453) Sales of Water and Water Power
19
RentFromElectricProperty
(454) Rent from Electric Property
4,710,868
4,037,929
20
InterdepartmentalRents
(455) Interdepartmental Rents
21
OtherElectricRevenue
(456) Other Electric Revenues
(f)
17,859,557
14,546,110
22
RevenuesFromTransmissionOfElectricityOfOthers
(456.1) Revenues from Transmission of Electricity of Others
79,891,482
86,147,015
23
RegionalTransmissionServiceRevenues
(457.1) Regional Control Service Revenues
633,633
621,204
24
MiscellaneousRevenue
(457.2) Miscellaneous Revenues
25
OtherMiscellaneousOperatingRevenues
Other Miscellaneous Operating Revenues
26
OtherOperatingRevenues
TOTAL Other Operating Revenues
107,290,444
109,116,931
27
ElectricOperatingRevenues
TOTAL Electric Operating Revenues
(g)
2,283,146,985
2,108,154,563


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: ResidentialSales

Includes revenues of $20,953 for distribution only service in the Illinois jurisdiction.

(b) Concept: SmallOrCommercialSalesElectricOperatingRevenue

Includes revenues of $1,182,308 for distribution only service in the Illinois jurisdiction.

 

Small (or commercial) generally includes commercial and industrial customers with a demand of 200 kw or less.

Large (or industrial) includes the remainder.

(c) Concept: LargeOrIndustrialSalesElectricOperatingRevenue

Includes revenues of $119,686 for distribution only service in the Illinois jurisdiction.

(d) Concept: PublicStreetAndHighwayLighting

Unmetered Sales:

All sales in account 444, private lighting sales included in account 440 and account 442 (small), and directional lighting sales included in account 442 (small) are billed at a set rate. Kilowatt hours are determined by type and size of lamp.

(e) Concept: OtherSalesToPublicAuthorities

Includes revenues of $150,838 for distribution only service in the Illinois jurisdiction.

(f) Concept: OtherElectricRevenue

Other Electric Revenues includes the amounts shown below:

 

Steam Sales $ 5,572,192

Renewable Energy Credit Sales 6,008

Other 12,281,357

Total $ 17,859,557

(g) Concept: ElectricOperatingRevenues

Column (b) through (e) contains Unbilled Revenues in lines 2, 4, 5, and 7.

(h) Concept: MegawattHoursSoldResidentialSales

Includes 446 mWh sales for distribution only service in the Illinois jurisdiction.

(i) Concept: MegawattHoursSoldSmallOrCommercial

Includes 60,501 mWh sales for distribution only service in the Illinois jurisdiction.

(j) Concept: MegawattHoursSoldLargeOrIndustrial

Includes 8,292 mWh sales for distribution only service in the Illinois jurisdiction.

(k) Concept: MegawattHoursSoldOtherSalesToPublicAuthorities

Includes 7,877 mWh sales for distribution only service in the Illinois jurisdiction.

(l) Concept: MegawattHoursSoldSalesToUltimateConsumers

Reconciliation of sales to Ultimate Consumers (in mWhs)

Sales per page 301, line 10, column (d) 25,927,688

less: Illinois distribution only sales (77,116)

Sales per page 401a, line 22, column (b) 25,850,572

(m) Concept: MegawattHoursSoldSalesToUltimateConsumers
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 22, Column: b, Value: 0
(n) Concept: MegawattHoursSoldSalesToUltimateConsumers
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 22, Column: b, Value: 25850572
(o) Concept: AverageNumberOfCustomersPerMonthResidentialSales

Includes 76 average customers for distribution only service in the Illinois jurisdiction.

(p) Concept: AverageNumberOfCustomersPerMonthSmallOrCommercial

Includes 200 average customers for distribution only service in the Illinois jurisdiction.

(q) Concept: AverageNumberOfCustomersPerMonthLargeOrIndustrial

Includes 1 average customers for distribution only service in the Illinois jurisdiction.

(r) Concept: AverageNumberOfCustomersPerMonthOtherSalesToPublicAuthorities

Includes 17 average customers for distribution only service in the Illinois jurisdiction.


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Scheduling, system control, and
2
dispatching services
164,886
320,557
487,558
633,633
46
TOTAL
164,886
320,557
487,558
633,633


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Residential
2
09
12
3
10
2
921
669,574
13,901,545
0.4605
4
AL
10,849
1,601,116
0.1476
5
RBN
1
82
0.082
6
RBS
12
1,002
0.0835
7
RES
1
69
0.069
8
RS
6,716,191
691,927,760
669,574
13,901,545
0.103
9
RSE
18,465
1,097,716
669,574
13,901,545
0.0594
10
RSH
1,781
148,480
669,574
13,901,545
0.0834
11
RST
287
28,363
669,574
13,901,545
0.0988
12
RSW
10,438
810,717
669,574
13,901,545
0.0777
13
SAL
100
10,510
669,574
13,901,545
0.1051
14
RSR (Distribution Only)
446
20,953
669,574
13,901,545
0.047
15
Unbilled Revenue
4,487
507,000
0.113
16
(a)
MISC. ADJUSTMENTS (See Note A)
782,278
17
TOTAL RESIDENTIAL
6,763,028
695,918,807
669,574
13,901,545
0.1029
18
Commercial
19
AL
26,811
3,144,771
669,574
13,901,545
0.1173
20
GD
2,085,997
156,619,343
669,574
13,901,545
0.0751
21
GDH
6,121
312,125
669,574
13,901,545
0.051
22
GDT
56,853
4,039,104
669,574
13,901,545
0.071
23
GE
1,711,378
154,002,569
669,574
13,901,545
0.09
24
GEH
1,832
133,538
669,574
13,901,545
0.0729
25
GET
22,174
1,857,336
669,574
13,901,545
0.0838
26
GSH
88
3,652
669,574
13,901,545
0.0415
27
GSW
8
799
669,574
13,901,545
0.0999
28
SAL
356
47,708
669,574
13,901,545
0.134
29
TC
2
254
669,574
13,901,545
0.127
30
ALR (Distribution Only)
161
12,793
669,574
13,901,545
0.0795
31
GDR (Distribution Only)
48,615
832,481
669,574
13,901,545
0.0171
32
GER (Distribution Only)
11,725
337,034
669,574
13,901,545
0.0287
33
Unbilled Revenue
15,042
1,375,000
0.0914
34
MISC. ADJUSTMENTS (See Note A)
4,542,669
35
TOTAL COMMERCIAL
3,957,079
315,425,838
669,574
13,901,545
0.0797
36
Industrial
37
AL
1,273
138,373
669,574
13,901,545
0.1087
38
ICR
6,268,258
312,248,658
669,574
13,901,545
0.0498
39
LPT
23,516
1,129,603
669,574
13,901,545
0.048
40
LS
5,001,637
298,437,245
669,574
13,901,545
0.0597
41
LSH
3,295
157,253
669,574
13,901,545
0.0477
42
LST
1,116,867
68,505,115
669,574
13,901,545
0.0613
43
SAL
186
19,279
669,574
13,901,545
0.1037
44
SS
595,239
30,426,749
669,574
13,901,545
0.0511
45
SST
152,917
8,703,931
669,574
13,901,545
0.0569
46
VLT
428,712
21,707,748
669,574
13,901,545
0.0506
47
LSR (Distribution Only)
8,293
119,686
669,574
13,901,545
0.0144
48
UNBILLED REVENUE
4,918
1,046,000
0.2127
49
MISC. ADJUSTMENTS (See Note A)
17,794,770
50
TOTAL INDUSTRIAL
13,595,275
758,342,410
669,574
13,901,545
0.0558
51
Public Authority
52
AL
4,176
520,300
669,574
13,901,545
0.1246
53
GD
237,235
17,582,190
669,574
13,901,545
0.0741
54
GDH
352
24,203
669,574
13,901,545
0.0688
55
GDT
17,960
1,320,781
669,574
13,901,545
0.0735
56
GE
213,781
18,129,469
669,574
13,901,545
0.0848
57
GEH
112
7,792
669,574
13,901,545
0.0696
58
GEP
1,432
106,237
669,574
13,901,545
0.0742
59
GET
2,415
210,119
669,574
13,901,545
0.087
60
GSH
10
378
669,574
13,901,545
0.0378
61
GSW
1
112
669,574
13,901,545
0.112
62
ICR
19,684
988,625
669,574
13,901,545
0.0502
63
LS
761,718
48,900,860
669,574
13,901,545
0.0642
64
LSH
1,114
61,863
669,574
13,901,545
0.0555
65
LST
121,947
7,417,147
669,574
13,901,545
0.0608
66
MWP
48,884
3,640,562
669,574
13,901,545
0.0745
67
RS
1,922
219,349
669,574
13,901,545
0.1141
68
SAL
601
57,377
669,574
13,901,545
0.0955
69
SS
20,278
1,167,109
669,574
13,901,545
0.0576
70
TC
5,280
496,845
669,574
13,901,545
0.0941
71
VLT
56,692
3,082,000
669,574
13,901,545
0.0544
72
ALR (Distribution Only)
2
250
0.125
73
GDR (Distribution Only)
5,723
95,449
669,574
13,901,545
0.0167
74
GER (Distribution Only)
2,152
55,139
669,574
13,901,545
0.0256
75
UNBILLED REVENUE
347
113,000
0.3256
76
MISC. ADJUSTMENTS (See Note A)
1,244,155
77
TOTAL PUBLIC AUTHORITY
1,523,124
105,215,311
669,574
13,901,545
0.0691
78
Public Street/Highway Lighting
79
SAL
418
49,382
669,574
13,901,545
0.1181
80
SL
66,384
15,063,959
669,574
13,901,545
0.2269
81
MISC. ADJUSTMENTS (See Note A)
16,462
82
TOTAL PUBLIC STREET/HIGHWAY LIGHT
66,802
15,129,803
669,574
13,901,545
0.2265
83
Interdepartmental Sales
84
AL
23
2,543
669,574
13,901,545
0.1106
85
GD
1,790
123,871
669,574
13,901,545
0.0692
86
GE
769
67,917
669,574
13,901,545
0.0883
87
LS
19,798
1,054,449
669,574
13,901,545
0.0533
88
TOTAL INTERDEPARTMENTAL SALES
22,380
1,248,780
669,574
13,901,545
0.0558
41 TOTAL Billed - All Accounts
25,943,508
1,894,321,949
779,803
33,269
0.073
42 TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
(b)
15,820
3,041,000
0.1922
43 TOTAL - All Accounts
25,927,688
1,891,280,949
779,803
33,249
0.0729


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfNumberAndTitleOfRateSchedule

Miscellaneous adjustments are mainly comprised of over/under adjustments related to rider mechanisms.

(b) Concept: MegawattHoursOfElectricitySoldByRateSchedulesUnbilled
Duplicate fact discrepancy. Schedule: 300 - Schedule - Electric Operating Revenues - Unbilled Revenues, Row: 1, Column: d12, Value: 15820

Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
KCPL Greater Missouri Operations
419
11,523
11,523
2
Lincoln Electric Systems
50
282,884
7,200,000
4,550,186
11,750,186
3
Midcontinent Independent System Operat.
10,712,205
221,756
230,932,143
38,056,944
269,210,843
4
NRG Power Marketing
178,169
178,169
5
PJM
149,008
3,671,965
3,671,965
6
Southwest Power Pool
36,335
1,306,707
442,199
1,748,906
15
Subtotal - RQ
16
Subtotal-Non-RQ
(b)
11,180,851
7,599,925
240,472,524
38,499,143
286,571,592
17 Total
11,180,851
7,599,925
240,472,524
38,499,143
286,571,592


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: OtherChargesRevenueSalesForResale

Breakdown of charges in Column (j) :

MISO - Revenue Sufficiency Guarantee

($4,763,939)

MISO - Revenue Neutrality Uplift

(2,019,338)

Loss Repay Energy

 

 

(7,561,266)

Ancillary Services

 

 

(6,274,098)

Financial Transmission Rights

 

(17,880,502)

 

 

 

 

($38,499,143)

(b) Concept: MegawattHoursSoldNonRequirementsSales
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 24, Column: b, Value: 0

Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
9,794,784
9,566,322
5
FuelSteamPowerGeneration
(501) Fuel
264,201,587
230,333,670
6
SteamExpensesSteamPowerGeneration
(502) Steam Expenses
17,592,866
16,526,640
7
SteamFromOtherSources
(503) Steam from Other Sources
8
SteamTransferredCredit
(Less) (504) Steam Transferred-Cr.
9
ElectricExpensesSteamPowerGeneration
(505) Electric Expenses
2,658,833
3,184,442
10
MiscellaneousSteamPowerExpenses
(506) Miscellaneous Steam Power Expenses
10,480,096
9,541,112
11
RentsSteamPowerGeneration
(507) Rents
72,562
196,894
12
Allowances
(509) Allowances
64,543
110,053
13
SteamPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 4 thru 12)
304,720,147
269,065,345
14
SteamPowerGenerationMaintenanceAbstract
Maintenance
15
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
(510) Maintenance Supervision and Engineering
5,231,175
5,148,326
16
MaintenanceOfStructuresSteamPowerGeneration
(511) Maintenance of Structures
4,325,527
2,977,321
17
MaintenanceOfBoilerPlantSteamPowerGeneration
(512) Maintenance of Boiler Plant
29,847,477
33,529,789
18
MaintenanceOfElectricPlantSteamPowerGeneration
(513) Maintenance of Electric Plant
7,894,302
12,091,500
19
MaintenanceOfMiscellaneousSteamPlant
(514) Maintenance of Miscellaneous Steam Plant
5,968,287
5,366,559
20
SteamPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 15 thru 19)
53,266,768
59,113,495
21
PowerProductionExpensesSteamPower
TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
357,986,915
328,178,840
22
NuclearPowerGenerationAbstract
B. Nuclear Power Generation
23
NuclearPowerGenerationOperationAbstract
Operation
24
OperationSupervisionAndEngineeringNuclearPowerGeneration
(517) Operation Supervision and Engineering
16,650,863
16,139,734
25
NuclearFuelExpense
(518) Fuel
23,215,032
23,792,166
26
CoolantsAndWater
(519) Coolants and Water
1,813,703
2,027,301
27
SteamExpensesNuclearPowerGeneration
(520) Steam Expenses
5,018,243
5,684,207
28
SteamFromOtherSourcesNuclearPowerGeneration
(521) Steam from Other Sources
29
SteamTransferredCreditNuclearPowerGeneration
(Less) (522) Steam Transferred-Cr.
30
ElectricExpensesNuclearPowerGeneration
(523) Electric Expenses
99,651
100,506
31
MiscellaneousNuclearPowerExpenses
(524) Miscellaneous Nuclear Power Expenses
19,649,709
20,696,963
32
RentsNuclearPowerGeneration
(525) Rents
33
NuclearPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of lines 24 thru 32)
66,447,201
68,440,877
34
NuclearPowerGenerationMaintenanceAbstract
Maintenance
35
MaintenanceSupervisionAndEngineeringNuclearPowerGeneration
(528) Maintenance Supervision and Engineering
13,323,939
13,665,309
36
MaintenanceOfStructuresNuclearPowerGeneration
(529) Maintenance of Structures
2,033,916
2,244,063
37
MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration
(530) Maintenance of Reactor Plant Equipment
2,931,046
3,896,420
38
MaintenanceOfElectricPlantNuclearPowerGeneration
(531) Maintenance of Electric Plant
3,995,069
4,262,298
39
MaintenanceOfMiscellaneousNuclearPlant
(532) Maintenance of Miscellaneous Nuclear Plant
2,966,883
2,915,827
40
NuclearPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 35 thru 39)
25,250,853
26,983,917
41
PowerProductionExpensesNuclearPower
TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
91,698,054
95,424,794
42
HydraulicPowerGenerationAbstract
C. Hydraulic Power Generation
43
HydraulicPowerGenerationOperationAbstract
Operation
44
OperationSupervisionAndEngineeringHydraulicPowerGeneration
(535) Operation Supervision and Engineering
619
2,156
45
WaterForPower
(536) Water for Power
46
HydraulicExpenses
(537) Hydraulic Expenses
47
ElectricExpensesHydraulicPowerGeneration
(538) Electric Expenses
47,413
60,043
48
MiscellaneousHydraulicPowerGenerationExpenses
(539) Miscellaneous Hydraulic Power Generation Expenses
134
475
49
RentsHydraulicPowerGeneration
(540) Rents
50
HydraulicPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 44 thru 49)
48,166
62,674
51
HydraulicPowerGenerationContinuedAbstract
C. Hydraulic Power Generation (Continued)
52
HydraulicPowerGenerationMaintenanceAbstract
Maintenance
53
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
(541) Mainentance Supervision and Engineering
8,168
8,066
54
MaintenanceOfStructuresHydraulicPowerGeneration
(542) Maintenance of Structures
55
MaintenanceOfReservoirsDamsAndWaterways
(543) Maintenance of Reservoirs, Dams, and Waterways
4,238
13,079
56
MaintenanceOfElectricPlantHydraulicPowerGeneration
(544) Maintenance of Electric Plant
84,792
1,195,981
57
MaintenanceOfMiscellaneousHydraulicPlant
(545) Maintenance of Miscellaneous Hydraulic Plant
991
1,509
58
HydraulicPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 53 thru 57)
98,189
1,218,635
59
PowerProductionExpensesHydraulicPower
TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
146,355
1,281,309
60
OtherPowerGenerationAbstract
D. Other Power Generation
61
OtherPowerGenerationOperationAbstract
Operation
62
OperationSupervisionAndEngineeringOtherPowerGeneration
(546) Operation Supervision and Engineering
2,814,236
2,907,192
63
Fuel
(547) Fuel
24,980,056
18,195,600
64
GenerationExpenses
(548) Generation Expenses
2,249,762
2,010,238
64.1
OperationOfEnergyStorageEquipment
(548.1) Operation of Energy Storage Equipment
65
MiscellaneousOtherPowerGenerationExpenses
(549) Miscellaneous Other Power Generation Expenses
2,597,391
2,214,131
66
RentsOtherPowerGeneration
(550) Rents
19,465,755
16,865,370
67
OtherPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 62 thru 67)
52,107,200
42,192,531
68
OtherPowerGenerationMaintenanceAbstract
Maintenance
69
MaintenanceSupervisionAndEngineeringOtherPowerGeneration
(551) Maintenance Supervision and Engineering
658,170
702,644
70
MaintenanceOfStructures
(552) Maintenance of Structures
1,407,331
2,761,875
71
MaintenanceOfGeneratingAndElectricPlant
(553) Maintenance of Generating and Electric Plant
101,699,315
77,147,978
71.1
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration
(553.1) Maintenance of Energy Storage Equipment
72
MaintenanceOfMiscellaneousOtherPowerGenerationPlant
(554) Maintenance of Miscellaneous Other Power Generation Plant
375,487
518,493
73
OtherPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 69 thru 72)
104,140,303
81,130,990
74
PowerProductionExpensesOtherPower
TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
156,247,503
123,323,521
75
OtherPowerSuplyExpensesAbstract
E. Other Power Supply Expenses
76
PurchasedPower
(555) Purchased Power
139,290,321
122,925,680
76.1
PowerPurchasedForStorageOperations
(555.1) Power Purchased for Storage Operations
77
SystemControlAndLoadDispatchingElectric
(556) System Control and Load Dispatching
1,901,526
2,501,718
78
OtherExpensesOtherPowerSupplyExpenses
(557) Other Expenses
736,878
5,784,429
79
OtherPowerSupplyExpense
TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)
141,928,725
131,211,827
80
PowerProductionExpenses
TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)
748,007,552
679,420,291
81
TransmissionExpensesAbstract
2. TRANSMISSION EXPENSES
82
TransmissionExpensesOperationAbstract
Operation
83
OperationSupervisionAndEngineeringElectricTransmissionExpenses
(560) Operation Supervision and Engineering
2,698,584
2,024,183
85
LoadDispatchReliability
(561.1) Load Dispatch-Reliability
534,799
550,846
86
LoadDispatchMonitorAndOperateTransmissionSystem
(561.2) Load Dispatch-Monitor and Operate Transmission System
782,471
790,952
87
LoadDispatchTransmissionServiceAndScheduling
(561.3) Load Dispatch-Transmission Service and Scheduling
194,512
196,205
88
SchedulingSystemControlAndDispatchServices
(561.4) Scheduling, System Control and Dispatch Services
4,431,800
4,295,960
89
ReliabilityPlanningAndStandardsDevelopment
(561.5) Reliability, Planning and Standards Development
1,874,240
1,850,599
90
TransmissionServiceStudies
(561.6) Transmission Service Studies
4,822
91
GenerationInterconnectionStudies
(561.7) Generation Interconnection Studies
19,895
20,528
92
ReliabilityPlanningAndStandardsDevelopmentServices
(561.8) Reliability, Planning and Standards Development Services
1,593,387
1,542,528
93
StationExpensesTransmissionExpense
(562) Station Expenses
2,183,271
2,057,349
93.1
OperationOfEnergyStorageEquipmentTransmissionExpense
(562.1) Operation of Energy Storage Equipment
94
OverheadLineExpense
(563) Overhead Lines Expenses
549,355
489,638
95
UndergroundLineExpensesTransmissionExpense
(564) Underground Lines Expenses
96
TransmissionOfElectricityByOthers
(565) Transmission of Electricity by Others
54,427,719
52,563,457
97
MiscellaneousTransmissionExpenses
(566) Miscellaneous Transmission Expenses
17,139
253,055
98
RentsTransmissionElectricExpense
(567) Rents
1,632,310
1,403,200
99
TransmissionOperationExpense
TOTAL Operation (Enter Total of Lines 83 thru 98)
70,939,482
68,043,322
100
TransmissionMaintenanceAbstract
Maintenance
101
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses
(568) Maintenance Supervision and Engineering
102
MaintenanceOfStructuresTransmissionExpense
(569) Maintenance of Structures
103
MaintenanceOfComputerHardwareTransmission
(569.1) Maintenance of Computer Hardware
17,530
50,197
104
MaintenanceOfComputerSoftwareTransmission
(569.2) Maintenance of Computer Software
277
42,417
105
MaintenanceOfCommunicationEquipmentElectricTransmission
(569.3) Maintenance of Communication Equipment
45,948
71,633
106
MaintenanceOfMiscellaneousRegionalTransmissionPlant
(569.4) Maintenance of Miscellaneous Regional Transmission Plant
107
MaintenanceOfStationEquipmentTransmission
(570) Maintenance of Station Equipment
1,502,622
2,105,579
107.1
MaintenanceOfEnergyStorageEquipmentTransmission
(570.1) Maintenance of Energy Storage Equipment
108
MaintenanceOfOverheadLinesTransmission
(571) Maintenance of Overhead Lines
2,685,042
7,077,835
109
MaintenanceOfUndergroundLinesTransmission
(572) Maintenance of Underground Lines
5,155
110
MaintenanceOfMiscellaneousTransmissionPlant
(573) Maintenance of Miscellaneous Transmission Plant
111
TransmissionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 101 thru 110)
4,251,419
9,352,816
112
TransmissionExpenses
TOTAL Transmission Expenses (Total of Lines 99 and 111)
75,190,901
77,396,138
113
RegionalMarketExpensesAbstract
3. REGIONAL MARKET EXPENSES
114
RegionalMarketExpensesOperationAbstract
Operation
115
OperationSupervision
(575.1) Operation Supervision
116
DayAheadAndRealTimeMarketAdministration
(575.2) Day-Ahead and Real-Time Market Facilitation
117
TransmissionRightsMarketAdministration
(575.3) Transmission Rights Market Facilitation
118
CapacityMarketAdministration
(575.4) Capacity Market Facilitation
119
AncillaryServicesMarketAdministration
(575.5) Ancillary Services Market Facilitation
120
MarketMonitoringAndCompliance
(575.6) Market Monitoring and Compliance
121
MarketFacilitationMonitoringAndComplianceServices
(575.7) Market Facilitation, Monitoring and Compliance Services
6,385,011
5,202,792
122
RentsRegionalMarketExpenses
(575.8) Rents
123
RegionalMarketOperationExpense
Total Operation (Lines 115 thru 122)
6,385,011
5,202,792
124
RegionalMarketExpensesMaintenanceAbstract
Maintenance
125
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses
(576.1) Maintenance of Structures and Improvements
126
MaintenanceOfComputerHardware
(576.2) Maintenance of Computer Hardware
127
MaintenanceOfComputerSoftware
(576.3) Maintenance of Computer Software
128
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses
(576.4) Maintenance of Communication Equipment
129
MaintenanceOfMiscellaneousMarketOperationPlant
(576.5) Maintenance of Miscellaneous Market Operation Plant
130
RegionalMarketMaintenanceExpense
Total Maintenance (Lines 125 thru 129)
131
RegionalMarketExpenses
TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)
6,385,011
5,202,792
132
DistributionExpensesAbstract
4. DISTRIBUTION EXPENSES
133
DistributionExpensesOperationAbstract
Operation
134
OperationSupervisionAndEngineeringDistributionExpense
(580) Operation Supervision and Engineering
8,600,229
8,764,332
135
LoadDispatching
(581) Load Dispatching
474,837
464,212
136
StationExpensesDistribution
(582) Station Expenses
4,563,752
4,694,714
137
OverheadLineExpenses
(583) Overhead Line Expenses
2,869,483
3,552,039
138
UndergroundLineExpenses
(584) Underground Line Expenses
3,156,831
3,641,659
138.1
OperationOfEnergyStorageEquipmentDistribution
(584.1) Operation of Energy Storage Equipment
139
StreetLightingAndSignalSystemExpenses
(585) Street Lighting and Signal System Expenses
156
140
MeterExpenses
(586) Meter Expenses
2,558,200
2,768,363
141
CustomerInstallationsExpenses
(587) Customer Installations Expenses
1,953,482
2,261,297
142
MiscellaneousDistributionExpenses
(588) Miscellaneous Expenses
11,120,141
9,346,558
143
RentsDistributionExpense
(589) Rents
290,643
228,887
144
DistributionOperationExpensesElectric
TOTAL Operation (Enter Total of Lines 134 thru 143)
35,587,754
35,722,061
145
DistributionExpensesMaintenanceAbstract
Maintenance
146
MaintenanceSupervisionAndEngineering
(590) Maintenance Supervision and Engineering
142,339
146,861
147
MaintenanceOfStructuresDistributionExpense
(591) Maintenance of Structures
148
MaintenanceOfStationEquipment
(592) Maintenance of Station Equipment
2,380,070
3,406,775
148.1
MaintenanceOfEnergyStorageEquipment
(592.2) Maintenance of Energy Storage Equipment
149
MaintenanceOfOverheadLines
(593) Maintenance of Overhead Lines
37,057,198
42,254,693
150
MaintenanceOfUndergroundLines
(594) Maintenance of Underground Lines
3,374,578
3,665,772
151
MaintenanceOfLineTransformers
(595) Maintenance of Line Transformers
152
MaintenanceOfStreetLightingAndSignalSystems
(596) Maintenance of Street Lighting and Signal Systems
1,554,535
1,856,324
153
MaintenanceOfMeters
(597) Maintenance of Meters
632,858
627,482
154
MaintenanceOfMiscellaneousDistributionPlant
(598) Maintenance of Miscellaneous Distribution Plant
14,029
962,584
155
DistributionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 146 thru 154)
45,155,607
52,920,491
156
DistributionExpenses
TOTAL Distribution Expenses (Total of Lines 144 and 155)
80,743,361
88,642,552
157
CustomerAccountsExpensesAbstract
5. CUSTOMER ACCOUNTS EXPENSES
158
CustomerAccountsExpensesOperationsAbstract
Operation
159
SupervisionCustomerAccountExpenses
(901) Supervision
1,448,835
1,571,896
160
MeterReadingExpenses
(902) Meter Reading Expenses
5,156,265
4,756,711
161
CustomerRecordsAndCollectionExpenses
(903) Customer Records and Collection Expenses
16,695,325
15,583,671
162
UncollectibleAccounts
(904) Uncollectible Accounts
6,061,997
5,736,998
163
MiscellaneousCustomerAccountsExpenses
(905) Miscellaneous Customer Accounts Expenses
336,614
291,125
164
CustomerAccountExpenses
TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)
29,699,036
27,940,401
165
CustomerServiceAndInformationalExpensesAbstract
6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166
CustomerServiceAndInformationalExpensesOperationAbstract
Operation
167
SupervisionCustomerServiceAndInformationExpenses
(907) Supervision
168
CustomerAssistanceExpenses
(908) Customer Assistance Expenses
115,275,131
106,884,885
169
InformationalAndInstructionalAdvertisingExpenses
(909) Informational and Instructional Expenses
184,325
528,670
170
MiscellaneousCustomerServiceAndInformationalExpenses
(910) Miscellaneous Customer Service and Informational Expenses
69,174
69,842
171
CustomerServiceAndInformationExpenses
TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)
115,528,630
107,483,397
172
SalesExpenseAbstract
7. SALES EXPENSES
173
SalesExpenseOperationAbstract
Operation
174
SupervisionSalesExpense
(911) Supervision
175
DemonstratingAndSellingExpenses
(912) Demonstrating and Selling Expenses
3,703,487
3,524,272
176
AdvertisingExpenses
(913) Advertising Expenses
177
MiscellaneousSalesExpenses
(916) Miscellaneous Sales Expenses
345,707
244,421
178
SalesExpenses
TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
4,049,194
3,768,693
179
AdministrativeAndGeneralExpensesAbstract
8. ADMINISTRATIVE AND GENERAL EXPENSES
180
AdministrativeAndGeneralExpensesOperationAbstract
Operation
181
AdministrativeAndGeneralSalaries
(920) Administrative and General Salaries
26,066,202
24,986,346
182
OfficeSuppliesAndExpenses
(921) Office Supplies and Expenses
14,392,767
13,694,642
183
AdministrativeExpensesTransferredCredit
(Less) (922) Administrative Expenses Transferred-Credit
4,352,760
3,392,315
184
OutsideServicesEmployed
(923) Outside Services Employed
9,323,069
7,338,208
185
PropertyInsurance
(924) Property Insurance
426,039
2,834,774
186
InjuriesAndDamages
(925) Injuries and Damages
5,913,467
5,885,706
187
EmployeePensionsAndBenefits
(926) Employee Pensions and Benefits
13,653,504
20,343,997
188
FranchiseRequirements
(927) Franchise Requirements
189
RegulatoryCommissionExpenses
(928) Regulatory Commission Expenses
3,932,213
4,835,347
190
DuplicateChargesCredit
(929) (Less) Duplicate Charges-Cr.
14,132,873
12,899,293
191
GeneralAdvertisingExpenses
(930.1) General Advertising Expenses
192
MiscellaneousGeneralExpenses
(930.2) Miscellaneous General Expenses
2,385,477
2,536,682
193
RentsAdministrativeAndGeneralExpense
(931) Rents
8,264,332
7,863,179
194
AdministrativeAndGeneralOperationExpense
TOTAL Operation (Enter Total of Lines 181 thru 193)
48,490,695
58,300,915
195
AdministrativeAndGeneralExpensesMaintenanceAbstract
Maintenance
196
MaintenanceOfGeneralPlant
(935) Maintenance of General Plant
1,065,339
1,228,845
197
AdministrativeAndGeneralExpenses
TOTAL Administrative & General Expenses (Total of Lines 194 and 196)
49,556,034
59,529,760
198
OperationsAndMaintenanceExpensesElectric
TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)
1,109,159,719
1,049,384,024


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Associated Electric Cooperative
(ab)
108,950
108,950
2
Clarke Electric Coop.
0.16
1,668
39,166
80,014
119,180
3
Exelon Power
1,304,640
33,099,991
33,099,991
4
Intercontinental Exchange
10,050
10,050
5
(a)
Iowa Private Generation
8
234
234
6
Kansas City Power and Light
2
65,028
65,028
7
Karbone, Inc.
36,652
36,652
8
KCPL Greater Missouri Operations
247
6,793
6,793
9
Lincoln Electric System
50
358,313
7,200,000
5,195,444
12,395,444
10
Macquarie Energy
179,800
5,063,440
5,063,440
11
Midcontinent Independent System Opera.
71
1,068,996
16,722
42,848,104
17,701,367
60,566,193
12
Nextera Energy
86,000
1,907,264
1,907,264
13
PJM
177,431
6,660,574
32,507
6,693,081
14
Southwest Power Pool
218,466
6,076,817
233,851
6,310,668
15
TransAlta
112,800
2,920,164
2,920,164
16
Beiermann, Brandon - QF
84
17
67
17
Bertch Cabinetry-QF
101
101
18
Carroll Area Wind Farm-QF
3
77,727
384,806
2,221,254
2,606,060
19
Christenson, James - QF
25
32
7
20
City of Davenport-AEP
1.3
8,270
309,432
211,146
520,578
21
Fluhrer-QF
84
84
22
Hunter-QF
16
1
15
23
Nelson-QF
8
8
24
Phearman, Joseph - QF
97
170
73
25
Storm Lake Wind Farm-AEP
192,917
3,858,340
3,858,340
26
Waste Management of Iowa-AEP
6.4
49,598
1,709,383
1,293,027
3,002,410
15 TOTAL
(ac)
3,836,883
9,659,094
111,507,854
18,123,377
139,290,325


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Purchases of electricity from Iowa Private Generation customers on the net-metering rate PG.

(b) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(c) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(d) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(e) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(f) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(g) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(h) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(i) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(j) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(k) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(l) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(m) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(n) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(o) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(p) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(q) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(r) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(s) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(t) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(u) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(v) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(w) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(x) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(y) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(z) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(aa) Concept: AverageMonthlyNonCoincidentPeakDemand
Original value: NA
(ab) Concept: OtherChargesOfPurchasedPower

 

Breakdown of charges in Column (l):

 

 

Brokerage Fees

 

$ 46,702

 

Ancillary Services

 

5,529,278

 

Transmission Losses

322,049

 

MISO CRD Failure and Excessive Deficient Charges

142,766

 

MISO Load Response

170,685

 

MISO Revenue Sufficiency Guarantee

3,361,081

 

MISO Revenue Neutrality Uplift

7,685,311

 

MISO Schedule 24

 

865,505

 

Total

 

$ 18,123,377

(ac) Concept: MegawattHoursPurchasedOtherThanStorage
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 10, Column: b, Value: 0

Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
(a)
Central Iowa Power Cooperative
MidAmerican Energy Company
Refer to Footnotes
Refer to Footnotes
Refer to Footnotes
34,301
34,301
2
(b)
Central Iowa Power Cooperative
Central Iowa Power Cooperative
Central Iowa Power Cooperative
Walter Scott Unit #3
Winterset Jct. Sub
20
494,644
494,644
211,292
211,292
3
(c)
Central Iowa Power Cooperative
Central Iowa Power Cooperative
Central Iowa Power Cooperative
Refer to Footnotes
Refer to Footnotes
32
226,524
226,524
41,917
41,917
4
(d)
Corn Belt Power Cooperative
Corn Belt Power Cooperative
Corn Belt Power Cooperative
Refer to Footnotes
Refer to Footnotes
25
449,488
449,488
150,000
150,000
5
(e)
Harlan Municipal Utilities
Harlan Municipal Utilities
Harlan Municipal Utilities
Hills Substation
Avoca Substation
5
39,002
39,002
67,307
67,307
6
(f)
Harlan Municipal Utilities
Harlan Municipal Utilities
Harlan Municipal Utilities
Sub 92
Hills Substation
2,230
2,230
7
(g)
ITC Midwest
MidAmerican Energy Company
ITC Midwest
Refer to Footnotes
Refer to Footnotes
54,033
54,033
8
(h)
Midwest ISO
Various
Various
Various
Various
78,789,760
78,789,760
9
(i)
Corn Belt Power Coop - NIMECA
Refer to Footnotes
Refer to Footnotes
Refer to Footnotes
Refer to Footnotes
540,642
540,642
35 TOTAL
82
1,209,658
1,209,658
1,101,722
78,789,760
79,891,482


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: PaymentByCompanyOrPublicAuthority

This agreement provides for the transfer of energy between CIPCO and MEC. CIPCO has numerous interconnection points (substations) on MEC transmission lines and vice versa. Billing demand is based on annual substation peak demand. This agreement is subject to four years' cancellation notice.

(b) Concept: PaymentByCompanyOrPublicAuthority

This agreement provides for Central Iowa Power Cooperative to transmit a portion of its share of the Walter Scott Unit No. 3 over the MEC transmission system (WSEC3-Winterset Jct.). This agreement is subject to four years' cancellation notice.

(c) Concept: PaymentByCompanyOrPublicAuthority

This agreement provides for Central Iowa Power Cooperative to transmit its ownership share of Louisa generation from Sub 92 through the Hills Substation. Transmission Service Schedule Nos. 1 and 3.

(d) Concept: PaymentByCompanyOrPublicAuthority

A transmission service agreement between MEC and Corn Belt Power Cooperative (CBPC) for the transmission of 25MW of Neal 4 generation capacity and associated energy over the MEC transmission system, dated November 1, 1983 and to remain in effect for the life of the unit.

(e) Concept: PaymentByCompanyOrPublicAuthority

This agreement provides for Harlan Municipal Utilities to transmit its share of the Louisa Generating Station over the MEC transmission system (Hills-Avoca). This agreement is subject to four years' cancellation notice.

(f) Concept: PaymentByCompanyOrPublicAuthority

This agreement provides for Harlan Municipal Utilities to transmit its share of Louisa Generating Station over the MEC transmission system (Sub 92-Hills). The total amount of megawatthours transferred is included in line 5, columns l and j. This agreement is subject to 3 years' cancellation notice.

(g) Concept: PaymentByCompanyOrPublicAuthority

Certain provisions of this agreement were assigned to ITC Midwest from Alliant (IES) which included the use of radial 69kV from Substation 56 to Walcott, Iowa. This agreement subject to three years' cancellation notice.

(h) Concept: PaymentByCompanyOrPublicAuthority

MidAmerican's share of Midwest ISO Open Access Transmission Tariff Revenues

(Schedules 7, 8, 9, 11, 26, 26-A, 37 & 38). The revenues are calculated as follows:

 

Schedule 7 $19,946,177

Schedule 8 987,328

Schedule 9 2,071,880

Schedule 26 245,704

Schedule 26-A 53,572,393

Schedule 37 2,606

Schedule 38 3,236

Schedule 11 (WDS Charges) 591,538

Amortization of MeC Accr for Estimated Sched 26-A Over/Under Collection 1,368,898

Total $78,789,760

(i) Concept: PaymentByCompanyOrPublicAuthority

This agreement provides for capacity assignment billings for use of certain Neal 3 transmission facilities by certain Neal 4 owners (CBPC and NIMECA (Algona, Bancroft, Coon Rapids, Graettinger, Grundy Center, Laurens, Milford, Spencer, and Webster City)).


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40
TOTAL


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Cornbelt
224,733
224,733
2
Midwest ISO
54,181,472
54,181,472
3
Southwestern Power Pool
21,514
21,514
TOTAL
54,427,719
54,427,719


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
239,024
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
COMPANY LABOR
568,002
7
DIRECTOR FEES
154,562
8
MORNINGSTAR INC
5,003
9
APPLIED ART AND TECHNOLOGY LC
5,149
10
QUAD CITY STEAMWHEELERS
5,535
11
COYOTE SPORTS PROPERTIES LLC
6,065
12
COUNCIL BLUFFS CHAMBER OF COMMERCE
6,120
13
CEDAR RAPIDS BALL CLUB INC
6,919
14
GREATER DES MOINES BASEBALL CO
6,919
15
FLYNN WRIGHT INC
7,086
16
SOUTH DAKOTA ELECTRIC UTILITY COMPANIES
7,459
17
GREATER CEDAR VALLEY ALLIANCE AND CHAMBER
7,469
18
MOORE SYNDICATION INC
8,513
19
GREATER DES MOINES MUSIC COALITION
9,281
20
SIOUXLAND CHAMBER OF COMMERCE
11,391
21
PROJECT BIONIC INC
11,733
22
WELLS FARGO BANK N A TRUST OPERATIONS
11,738
23
TAXPAYERS ASSOCIATION OF CENTRAL IOWA
13,838
24
EMPLOYEE EXP. REIMBURSE. FOR TRAVEL, MEALS, AND ENT.
15,424
25
METROLINK
16,818
26
2018/19 WRI CLEAN POWER COUNCIL DUES
18,750
27
2018 AWEA CORPORATE PARTNER DUES
20,000
28
IOWA STATE FAIR
20,020
29
ILLINOIS ENERGY ASSOCIATION
21,925
30
IOWA BASKETBALL HOLDINGS LLC
23,064
31
SAFEGUARD IOWA PARTNERSHIP
23,064
32
2018/19 AWWI PARTNER DUES
25,000
33
SPROUT SOCIAL INC
38,291
34
NORTH AMERICAN TRANSMISSION FORUM INC
43,172
35
BIRDS NEST
44,419
36
ASI SIGNAGE INNOVATIONS
50,081
37
WESTERN COAL TRAFFIC LEAGUE
55,000
38
IDEAL IMAGES INC
71,500
39
SCIENCE CENTER OF IOWA
73,804
40
STRATEGIC ELEMENTS LLC
78,629
41
IOWA UTILITY ASSOCIATION
117,552
42
AMORTIZE EEI DUES
434,670
43
SHARED FACILITY CHARGES - Use of Ruan building
4,274
44
OTHER (118 items < $5000)
98,214
46
MiscellaneousGeneralExpenses
TOTAL
2,385,477


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
11,452,907
11,452,907
2
Steam Production Plant
77,450,054
16,998,426
94,448,480
3
Nuclear Production Plant
18,190,177
18,190,177
4
Hydraulic Production Plant-Conventional
120,060
120,060
5
Hydraulic Production Plant-Pumped Storage
6
Other Production Plant
286,467,185
2,351,447
288,818,632
7
Transmission Plant
37,256,091
1,073
37,255,018
8
Distribution Plant
72,962,988
184,278
72,778,710
9
Regional Transmission and Market Operation
10
General Plant
17,875,113
1,809,173
19,684,286
11
Common Plant-Electric
12
TOTAL
510,321,668
19,164,522
13,262,080
542,748,270
B. Basis for Amortization Charges
Each franchise is amortized over its term. Limited term investments are amortized over their estimated useful lives to the Company. For example, a leasehold improvement is amortized over the remaining life of the lease.
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
456
0 years
0 years
16
2,539
0 years
0 years
17
10
0 years
0 years
18
22
0 years
0 years
19
0 years
0 years
20
1,250
0 years
5.41
(f)
7 years
21
4,277
0 years
0 years
22
0 years
0 years
23
0 years
0 years
24
1,473
0 years
0 years
25
350
0 years
0 years
26
10
0 years
0 years
27
18
0 years
0 years
28
0 years
0 years
29
52,836
0 years
19.45
0 years
30
54,687
0 years
0 years
31
0 years
0 years
32
0 years
0 years
33
115,015
0 years
1.54
(g)
22 years
34
376,243
0 years
2.85
(h)
22 years
35
58,113
0 years
1.41
(i)
22 years
36
37,557
0 years
1.84
(j)
22 years
37
5,993
0 years
0.9
(k)
22 years
38
34,880
0 years
3.8
(l)
25 years
39
627,801
0 years
0 years
40
0 years
0 years
41
0 years
0 years
42
101,246
0 years
2.67
(m)
32 years
43
230,440
0 years
2.66
(n)
32 years
44
93,271
0 years
2.68
(o)
32 years
45
26,369
0 years
2.98
(p)
32 years
46
0 years
(q)
32 years
47
451,326
0 years
0 years
48
0 years
0 years
49
0 years
0 years
50
3,323
0 years
0 years
51
1,873
0 years
0 years
52
283
0 years
0 years
53
3,270
0 years
0 years
54
0 years
0 years
55
2,941
0 years
7.58
(r)
4 years
56
11,690
0 years
0 years
57
0 years
0 years
58
1,226
0 years
0 years
59
87
0 years
0 years
60
8
0 years
0 years
61
113
0 years
0 years
62
75
0 years
0 years
63
4,068
0 years
22.93
(s)
6 years
64
5,577
0 years
0 years
65
0 years
0 years
66
46,135
0 years
3.33
(t)
17 years
67
300,496
0 years
3.28
(u)
17 years
68
37,809
0 years
2.23
(v)
17 years
69
34,295
0 years
3.95
(w)
17 years
70
1,794
0 years
2.01
(x)
17 years
71
15,416
0 years
19.27
(y)
9 years
72
435,945
0 years
0 years
73
0 years
0 years
74
35,988
0 years
1.77
(z)
22 years
75
205,630
0 years
2.03
(aa)
22 years
76
31,685
0 years
1.46
(ab)
22 years
77
28,667
0 years
1.86
(ac)
22 years
78
1,895
0 years
1.04
(ad)
22 years
79
3,190
0 years
42.85
(ae)
11 years
80
307,055
0 years
0 years
81
0 years
0 years
82
56,117
0 years
1.25
(af)
22 years
83
459,993
0 years
2.7
(ag)
22 years
84
70,672
0 years
2.97
(ah)
22 years
85
24,519
0 years
1.18
(ai)
22 years
86
6,522
0 years
1.07
(aj)
22 years
87
8,999
0 years
5.99
(ak)
5 years
88
626,822
0 years
0 years
89
0 years
0 years
90
123,784
0 years
1
(al)
22 years
91
499,380
0 years
2.16
(am)
22 years
92
111,253
0 years
2.3
(an)
22 years
93
58,608
0 years
1.66
(ao)
22 years
94
2,468
0 years
1.01
(ap)
22 years
95
13,958
0 years
15.34
(aq)
18 years
96
809,451
0 years
0 years
97
0 years
0 years
98
10,702
0 years
2.85
(ar)
7 years
99
19,622
0 years
9.87
(as)
7 years
100
8,239
0 years
1.4
(at)
7 years
101
5,756
0 years
2.98
(au)
7 years
102
442
0 years
5.14
(av)
7 years
103
6,284
0 years
0.01
(aw)
2 years
104
51,045
0 years
0 years
105
0 years
0 years
106
3,385,676
0 years
0 years
107
0 years
0 years
108
523,426
0 years
3.62
(ax)
14 years
109
523,426
0 years
0 years
110
0 years
0 years
111
408
0 years
4.42
(ay)
8 years
112
939
0 years
3.53
(az)
8 years
113
1,101
0 years
12.13
(ba)
8 years
114
506
0 years
3.37
(bb)
8 years
115
10
0 years
4.13
(bc)
8 years
116
2,964
0 years
0 years
117
0 years
0 years
118
0 years
0 years
119
677
0 years
1.25
(bd)
3 years
120
503
0 years
16.42
(be)
3 years
121
101
0 years
(bf)
3 years
122
10,734
0 years
0.44
(bg)
3 years
123
3,768
0 years
9.49
(bh)
3 years
124
114
0 years
(bi)
3 years
125
15,897
0 years
0 years
126
0 years
0 years
127
839
0 years
6.14
(bj)
2 years
128
312
0 years
1.71
(bk)
2 years
129
101
0 years
0.92
(bl)
2 years
130
17,148
0 years
2.37
(bm)
2 years
131
2,576
0 years
9.97
(bn)
2 years
132
166
0 years
4.32
(bo)
2 years
133
21,142
0 years
0 years
134
0 years
0 years
135
0 years
0 years
136
6,455
0 years
1.94
(bp)
16 years
137
2,356
0 years
1.93
(bq)
16 years
138
853
0 years
1.53
(br)
16 years
139
41,958
0 years
1.9
(bs)
16 years
140
9,008
0 years
2.9
(bt)
16 years
141
66
0 years
1.43
(bu)
16 years
142
60,696
0 years
0 years
143
0 years
0 years
144
101
0 years
3.67
(bv)
7 years
145
120
0 years
0.56
(bw)
7 years
146
4,901
0 years
0.11
(bx)
7 years
147
967
0 years
0.07
(by)
7 years
148
6,089
0 years
0 years
149
0 years
0 years
150
58
0 years
0.42
(bz)
12 years
151
2,168
0 years
3.01
(ca)
12 years
152
2,644
0 years
2.21
(cb)
12 years
153
174
0 years
0.19
(cc)
12 years
154
23,741
0 years
1.78
(cd)
12 years
155
3,976
0 years
3.43
(ce)
12 years
156
32,761
0 years
0 years
157
0 years
0 years
158
779
0 years
6.68
(cf)
2 years
159
375
0 years
(cg)
2 years
160
9,688
0 years
13.09
(ch)
2 years
161
780
0 years
7.01
(ci)
2 years
162
88
0 years
(cj)
2 years
163
11,710
0 years
0 years
164
0 years
0 years
165
1
0 years
9.98
(ck)
7 years
166
557
0 years
8.92
(cl)
7 years
167
689
0 years
10.33
(cm)
7 years
168
13,176
0 years
4.44
(cn)
7 years
169
1,484
0 years
3.63
(co)
7 years
170
108
0 years
5.74
(cp)
7 years
171
16,015
0 years
0 years
172
0 years
0 years
173
1,280
0 years
4.07
(cq)
13 years
174
34,806
0 years
3.82
(cr)
13 years
175
11,317
0 years
3.56
(cs)
13 years
176
245,648
0 years
3.79
(ct)
13 years
177
37,706
0 years
3.79
(cu)
13 years
178
330,757
0 years
0 years
179
0 years
0 years
180
819
0 years
5.31
(cv)
6 years
181
262,178
0 years
7.16
(cw)
6 years
182
18,702
0 years
5.66
(cx)
6 years
183
399
0 years
6.94
(cy)
6 years
184
3,181
0 years
1.65
(cz)
28 years
185
285,279
0 years
0 years
186
0 years
0 years
187
3,835
0 years
5.3
(da)
8 years
188
297,628
0 years
7.13
(db)
8 years
189
15,626
0 years
5.59
(dc)
8 years
190
153
0 years
5.69
(dd)
8 years
191
3,744
0 years
1.42
(de)
29 years
192
320,986
0 years
0 years
193
0 years
0 years
194
6,889
0 years
5.24
(df)
8 years
195
156,380
0 years
7.92
(dg)
8 years
196
18,852
0 years
4.9
(dh)
8 years
197
189
0 years
5.42
(di)
8 years
198
1,154
0 years
1.47
(dj)
38 years
199
183,464
0 years
0 years
200
0 years
0 years
201
14,158
0 years
5.07
(dk)
13 years
202
591,910
0 years
4.51
(dl)
13 years
203
41,499
0 years
4.55
(dm)
13 years
204
464
0 years
4.91
(dn)
13 years
205
3,383
0 years
1.72
(do)
38 years
206
651,414
0 years
0 years
207
0 years
0 years
208
744
0 years
5.21
(dp)
9 years
209
152
0 years
5.5
(dq)
9 years
210
40
0 years
4.93
(dr)
9 years
211
936
0 years
0 years
212
0 years
0 years
213
439
0 years
0.56
(ds)
10 years
214
203,643
0 years
5.1
(dt)
10 years
215
15,079
0 years
4.77
(du)
10 years
216
183
0 years
5.6
(dv)
10 years
217
842
0 years
1.64
(dw)
39 years
218
220,186
0 years
0 years
219
0 years
0 years
220
1,198
0 years
4.07
(dx)
10 years
221
268,381
0 years
5.14
(dy)
10 years
222
31,437
0 years
4.84
(dz)
10 years
223
2,461
0 years
1.79
(ea)
40 years
224
303,477
0 years
0 years
225
0 years
0 years
226
1,072
0 years
3.58
(eb)
10 years
227
339,804
0 years
5.43
(ec)
10 years
228
20,789
0 years
4.33
(ed)
10 years
229
1,823
0 years
1.8
(ee)
40 years
230
363,488
0 years
0 years
231
0 years
0 years
232
831
0 years
3.1
(ef)
10 years
233
307,572
0 years
5.11
(eg)
10 years
234
34,393
0 years
4.86
(eh)
10 years
235
2,493
0 years
1.77
(ei)
40 years
236
345,289
0 years
0 years
237
0 years
0 years
238
3,182
0 years
2.1
(ej)
33 years
239
652,022
0 years
2.4
(ek)
33 years
240
58,852
0 years
2.37
(el)
33 years
241
4,962
0 years
1.74
(em)
43 years
242
719,018
0 years
0 years
243
0 years
0 years
244
3,407
0 years
2.2
(en)
33 years
245
187,992
0 years
2.44
(eo)
33 years
246
13,755
0 years
2.12
(ep)
33 years
247
2,177
0 years
3.12
(eq)
23 years
248
207,331
0 years
0 years
249
0 years
0 years
250
24,722
0 years
1.29
0 years
251
24,722
0 years
0 years
252
0 years
0 years
253
1,581
0 years
2.14
(er)
34 years
254
289,545
0 years
2.46
(es)
34 years
255
36,731
0 years
2.39
(et)
34 years
256
290
0 years
2.67
(eu)
34 years
257
3,727
0 years
2.66
(ev)
29 years
258
331,874
0 years
0 years
259
0 years
0 years
260
620
0 years
2.03
(ew)
34 years
261
145,900
0 years
2.53
(ex)
34 years
262
13,251
0 years
2.33
(ey)
34 years
263
2,034
0 years
2.72
(ez)
29 years
264
161,805
0 years
0 years
265
0 years
0 years
266
1,347
0 years
2.32
(fa)
34 years
267
220,362
0 years
2.48
(fb)
34 years
268
16,711
0 years
2.33
(fc)
34 years
269
152
0 years
2.66
(fd)
34 years
270
3,017
0 years
3.11
(fe)
24 years
271
241,589
0 years
0 years
272
0 years
0 years
273
199
0 years
2.35
(ff)
36 years
274
363,935
0 years
2.52
(fg)
36 years
275
24,233
0 years
2.39
(fh)
36 years
276
4,647
0 years
2.9
(fi)
30 years
277
393,014
0 years
0 years
278
0 years
0 years
279
269
0 years
2.44
(fj)
36 years
280
184,293
0 years
2.52
(fk)
36 years
281
12,697
0 years
2.37
(fl)
36 years
282
2,532
0 years
3.3
(fm)
26 years
283
199,791
0 years
0 years
284
0 years
0 years
285
386
0 years
2.45
(fn)
36 years
286
221,669
0 years
2.53
(fo)
36 years
287
14,103
0 years
2.54
(fp)
36 years
288
2,969
0 years
3.3
(fq)
26 years
289
239,127
0 years
0 years
290
0 years
0 years
291
28,381
0 years
2.53
(fr)
27 years
292
702,646
0 years
2.53
(fs)
27 years
293
78,981
0 years
2.61
(ft)
27 years
294
10,323
0 years
3.98
(fu)
22 years
295
820,331
0 years
0 years
296
0 years
0 years
297
4,430
0 years
3.33
(fv)
27 years
298
202,135
0 years
3.47
(fw)
27 years
299
21,348
0 years
3.3
(fx)
27 years
300
3,020
0 years
3.32
(fy)
27 years
301
230,933
0 years
0 years
302
0 years
0 years
303
22,723
0 years
2.49
(fz)
38 years
304
402,312
0 years
2.51
(ga)
38 years
305
65,969
0 years
2.19
(gb)
38 years
306
7,861
0 years
3.97
(gc)
23 years
307
498,865
0 years
0 years
308
0 years
0 years
309
1,772
0 years
2.49
(gd)
38 years
310
332,073
0 years
2.51
(ge)
38 years
311
33,174
0 years
2.45
(gf)
38 years
312
6,235
0 years
3.98
(gg)
23 years
313
373,254
0 years
0 years
314
0 years
0 years
315
7,357
0 years
1.88
(gh)
39 years
316
433,639
0 years
2.57
(gi)
39 years
317
62,164
0 years
2.18
(gj)
39 years
318
7,401
0 years
1.38
(gk)
39 years
319
510,561
0 years
0 years
320
0 years
0 years
321
4,944
0 years
2.5
(gl)
39 years
322
203,938
0 years
2.52
(gm)
39 years
323
43,040
0 years
2.52
(gn)
39 years
324
4,086
0 years
2.11
(go)
39 years
325
256,008
0 years
0 years
326
0 years
0 years
327
6,470
0 years
1.89
N/A
(gp)
40 years
328
266,942
0 years
1
1.91
N/A
(gq)
40 years
329
65,681
0 years
1
2.02
N/A
(gr)
40 years
330
3,846
0 years
1.87
SL
(gs)
40 years
331
342,939
0 years
0 years
332
0 years
0 years
333
3,263
0 years
0.15
N/A
(gt)
40 years
334
134,642
0 years
1
0.15
N/A
(gu)
40 years
335
52,165
0 years
1
0.07
N/A
(gv)
40 years
336
2,771
0 years
0.24
SL
(gw)
25 years
337
192,841
0 years
0 years
338
0 years
0 years
339
1,054
0 years
N/A
(gx)
40 years
340
113,795
0 years
1
0.3
N/A
(gy)
40 years
341
10,915
0 years
1
1.26
N/A
(gz)
40 years
342
1,770
0 years
0.38
SL
(ha)
30 years
343
127,534
0 years
0 years
344
0 years
0 years
345
2,446
0 years
(hb)
40 years
346
349,556
0 years
1
0.84
(hc)
40 years
347
24,804
0 years
1
1.33
(hd)
40 years
348
4,661
0 years
0.77
(he)
40 years
349
381,467
0 years
0 years
350
9,422,590
0 years
0 years
351
0 years
0 years
352
60,240
0 years
1.27
(hf)
52 years
353
45,255
0 years
1.68
(hg)
52 years
354
663,083
0 years
1.55
(hh)
51 years
355
39,963
0 years
1.41
(hi)
42 years
356
596,333
0 years
2.33
(hj)
44 years
357
509,215
0 years
2.23
(hk)
49 years
358
1,267
0 years
1.88
(hl)
34 years
359
2,809
0 years
1.8
(hm)
33 years
360
154
0 years
1.29
(hn)
63 years
361
3
0 years
137.92
(ho)
4 years
362
0 years
0 years
363
1,918,316
0 years
0 years
364
0 years
0 years
365
4,517
0 years
1.3
(hp)
54 years
366
23,365
0 years
1.66
(hq)
50 years
367
513,222
0 years
1.61
(hr)
45 years
368
2,416
(e)
10 years
10.53
SQ
(hs)
10 years
369
421,606
0 years
2.63
(ht)
40 years
370
570,145
0 years
2.76
(hu)
39 years
371
73,184
0 years
2.38
(hv)
47 years
372
648,614
0 years
2.3
(hw)
45 years
373
392,087
0 years
2.17
(hx)
31 years
374
180,262
0 years
3.03
(hy)
48 years
375
73,405
0 years
6.34
(hz)
12 years
376
16,692
0 years
3.28
(ia)
21 years
377
110,041
0 years
3.18
(ib)
33 years
378
308
0 years
67.55
(ic)
6 years
379
0 years
0 years
380
3,029,248
0 years
0 years
381
0 years
0 years
382
520
0 years
1.49
(id)
42 years
383
232,112
0 years
2.1
(ie)
40 years
384
(a)
16,907
0 years
9.38
(if)
7 years
385
(b)
31,142
0 years
19.37
(ig)
3 years
386
5,311
0 years
4.84
(ih)
10 years
387
1,552
0 years
3.07
(ii)
12 years
388
37,593
0 years
6.41
(ij)
11 years
389
659
0 years
10.81
(ik)
7 years
390
17,081
0 years
3.74
(il)
7 years
391
(c)
36,475
0 years
6.27
(im)
6 years
392
(d)
1,930
0 years
10.84
(in)
1 year
393
4,275
0 years
8.91
(io)
4 years
394
385,557
0 years
0 years


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: DepreciablePlantBase

Account 391 on Line 33 represents office furniture/equipment.

(b) Concept: DepreciablePlantBase

Account 391 on Line 34 represents computer equipment.

(c) Concept: DepreciablePlantBase

Account 397 on Line 40 represents communication equipment.

(d) Concept: DepreciablePlantBase

Account 397 on Line 41 represents communication equipment interconnected with computer equipment.

(e) Concept: UtilityPlantEstimatedAverageServiceLife
Original value: 10
(f) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(g) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(h) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(i) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(j) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(k) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(l) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 25
(m) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 32
(n) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 32
(o) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 32
(p) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 32
(q) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 32
(r) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 4
(s) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 6
(t) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 17
(u) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 17
(v) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 17
(w) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 17
(x) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 17
(y) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 9
(z) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(aa) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(ab) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(ac) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(ad) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(ae) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 11
(af) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(ag) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(ah) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(ai) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(aj) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(ak) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 5
(al) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(am) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(an) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(ao) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(ap) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(aq) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 18
(ar) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(as) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(at) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(au) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(av) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(aw) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(ax) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 14
(ay) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8
(az) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8
(ba) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8
(bb) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8
(bc) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8
(bd) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 3
(be) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 3
(bf) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 3
(bg) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 3
(bh) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 3
(bi) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 3
(bj) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(bk) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(bl) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(bm) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(bn) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(bo) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(bp) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 16
(bq) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 16
(br) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 16
(bs) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 16
(bt) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 16
(bu) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 16
(bv) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(bw) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(bx) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(by) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(bz) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 12
(ca) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 12
(cb) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 12
(cc) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 12
(cd) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 12
(ce) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 12
(cf) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(cg) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(ch) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(ci) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(cj) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2
(ck) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(cl) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(cm) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(cn) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(co) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(cp) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7
(cq) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 13
(cr) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 13
(cs) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 13
(ct) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 13
(cu) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 13
(cv) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 6
(cw) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 6
(cx) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 6
(cy) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 6
(cz) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 28
(da) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8.42
(db) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8.42
(dc) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8.42
(dd) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8.42
(de) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 29
(df) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8
(dg) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8
(dh) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8
(di) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 8
(dj) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 38
(dk) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 13
(dl) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 13
(dm) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 13
(dn) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 13
(do) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 38
(dp) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 9
(dq) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 9
(dr) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 9
(ds) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(dt) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(du) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(dv) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(dw) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39
(dx) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(dy) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(dz) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(ea) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(eb) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(ec) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(ed) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(ee) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(ef) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(eg) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(eh) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(ei) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(ej) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 33
(ek) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 33
(el) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 33
(em) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 43
(en) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 33
(eo) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 33
(ep) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 33
(eq) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 23
(er) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(es) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(et) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(eu) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(ev) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 29
(ew) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(ex) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(ey) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(ez) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 29
(fa) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(fb) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(fc) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(fd) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 34
(fe) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 24
(ff) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 36
(fg) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 36
(fh) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 36
(fi) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 30
(fj) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 36
(fk) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 36
(fl) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 36
(fm) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 26
(fn) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 36
(fo) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 36
(fp) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 36
(fq) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 26
(fr) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 27
(fs) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 27
(ft) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 27
(fu) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 22
(fv) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 27
(fw) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 27
(fx) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 27
(fy) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 27
(fz) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 38
(ga) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 38
(gb) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 38
(gc) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 23
(gd) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 38
(ge) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 38
(gf) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 38
(gg) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 23
(gh) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39
(gi) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39
(gj) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39
(gk) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39
(gl) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39
(gm) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39
(gn) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39
(go) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39
(gp) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(gq) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(gr) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(gs) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(gt) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(gu) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(gv) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(gw) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 25
(gx) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(gy) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(gz) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(ha) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 30
(hb) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(hc) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(hd) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(he) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40
(hf) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 52.48
(hg) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 52.02
(hh) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 51.32
(hi) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 42.45
(hj) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 44.16
(hk) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 48.87
(hl) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 33.69
(hm) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 32.88
(hn) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 63.31
(ho) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 4
(hp) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 54.5
(hq) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 49.7
(hr) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 45.22
(hs) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10
(ht) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39.6
(hu) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 39.15
(hv) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 47.4
(hw) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 45.4
(hx) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 31.37
(hy) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 47.74
(hz) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 12.12
(ia) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 20.76
(ib) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 32.71
(ic) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: -6.03
(id) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 41.7
(ie) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 40.3
(if) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 7.42
(ig) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 2.73
(ih) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 9.91
(ii) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 11.79
(ij) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 10.62
(ik) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 6.98
(il) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 6.56
(im) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 6.13
(in) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 0.51
(io) Concept: UtilityPlantWeightedAverageRemainingLife
Original value: 4.35

Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
SDPUC Assessment
148,958
148,958
3
IUB/OCA Direct Assessment
500,227
500,227
5
IUB/OCA Remainder Assessment
2,424,448
2,424,448
7
FERC Assessment
2,158,612
2,158,612
9
2014 IL Electric Rate Case
10,071
10,071
19,303
10,071
9,232
11
2015 SD Electric Rate Case
22,701
22,701
57,699
22,701
34,998
13
2015 SD Gas Rate Case
24,788
24,788
61,969
1
24,787
37,182
46
TOTAL
5,232,245
57,560
5,289,805
138,971
1
57,559
81,412


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
B(1)
Electric Power Research Institute
139,024
139,024
2
B(4)
Iowa State University
100,000
100,000
3
TOTAL
239,024
239,024


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
38,482,522
4
SalariesAndWagesElectricOperationTransmission
Transmission
6,639,911
5
SalariesAndWagesElectricOperationRegionalMarket
Regional Market
6
SalariesAndWagesElectricOperationDistribution
Distribution
24,955,923
7
SalariesAndWagesElectricOperationCustomerAccounts
Customer Accounts
16,751,011
8
SalariesAndWagesElectricOperationCustomerServiceAndInformational
Customer Service and Informational
1,715
9
SalariesAndWagesElectricOperationSales
Sales
2,439,635
10
SalariesAndWagesElectricOperationAdministrativeAndGeneral
Administrative and General
27,358,217
11
SalariesAndWagesElectricOperation
TOTAL Operation (Enter Total of lines 3 thru 10)
116,628,934
12
SalariesAndWagesElectricMaintenanceAbstract
Maintenance
13
SalariesAndWagesElectricMaintenanceProduction
Production
20,064,825
14
SalariesAndWagesElectricMaintenanceTransmission
Transmission
1,165,632
15
SalariesAndWagesElectricMaintenanceRegionalMarket
Regional Market
16
SalariesAndWagesElectricMaintenanceDistribution
Distribution
16,122,139
17
SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral
Administrative and General
85,414
18
SalariesAndWagesElectricMaintenance
TOTAL Maintenance (Total of lines 13 thru 17)
37,438,010
19
SalariesAndWagesElectricOperationAndMaintenanceAbstract
Total Operation and Maintenance
20
SalariesAndWagesElectricProduction
Production (Enter Total of lines 3 and 13)
58,547,347
21
SalariesAndWagesElectricTransmission
Transmission (Enter Total of lines 4 and 14)
7,805,543
22
SalariesAndWagesElectricRegionalMarket
Regional Market (Enter Total of Lines 5 and 15)
23
SalariesAndWagesElectricDistribution
Distribution (Enter Total of lines 6 and 16)
41,078,062
24
SalariesAndWagesElectricCustomerAccounts
Customer Accounts (Transcribe from line 7)
16,751,011
25
SalariesAndWagesElectricCustomerServiceAndInformational
Customer Service and Informational (Transcribe from line 8)
1,715
26
SalariesAndWagesElectricSales
Sales (Transcribe from line 9)
2,439,635
27
SalariesAndWagesElectricAdministrativeAndGeneral
Administrative and General (Enter Total of lines 10 and 17)
27,443,631
28
SalariesAndWagesElectricOperationAndMaintenance
TOTAL Oper. and Maint. (Total of lines 20 thru 27)
154,066,944
4,263,742
158,330,686
29
SalariesAndWagesGasAbstract
Gas
30
SalariesAndWagesGasOperationAbstract
Operation
31
SalariesAndWagesGasOperationProductionManufacturedGas
Production - Manufactured Gas
19,873
32
SalariesAndWagesGasOperationProductionNaturalGas
Production-Nat. Gas (Including Expl. And Dev.)
33
SalariesAndWagesGasOperationOtherGasSupply
Other Gas Supply
1,872,365
34
SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing
Storage, LNG Terminaling and Processing
652,189
35
SalariesAndWagesGasOperationTransmission
Transmission
36
SalariesAndWagesGasOperationDistribution
Distribution
32,265,668
58
SalariesAndWagesGasCustomerAccounts
Customer Accounts
15,493,662
38
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational
1,431
39
SalariesAndWagesGasSales
Sales
700,085
40
SalariesAndWagesGasOperationAdministrativeAndGeneral
Administrative and General
4,941,828
41
SalariesAndWagesGasOperation
TOTAL Operation (Enter Total of lines 31 thru 40)
55,947,101
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
562,088
47
SalariesAndWagesGasMaintenanceTransmission
Transmission
48
SalariesAndWagesGasMaintenanceDistribution
Distribution
7,370,363
49
SalariesAndWagesGasMaintenanceAdministrativeAndGeneral
Administrative and General
60,986
50
SalariesAndWagesGasMaintenance
TOTAL Maint. (Enter Total of lines 43 thru 49)
7,993,437
51
SalariesAndWagesGasOperationAndMaintenanceAbstract
Total Operation and Maintenance
52
SalariesAndWagesGasProductionManufacturedGas
Production-Manufactured Gas (Enter Total of lines 31 and 43)
19,873
53
SalariesAndWagesGasProductionNaturalGas
Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54
SalariesAndWagesGasOtherGasSupply
Other Gas Supply (Enter Total of lines 33 and 45)
1,872,365
55
SalariesAndWagesGasStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing (Total of lines 31 thru
1,214,277
56
SalariesAndWagesGasTransmission
Transmission (Lines 35 and 47)
57
SalariesAndWagesGasDistribution
Distribution (Lines 36 and 48)
39,636,031
58
SalariesAndWagesGasCustomerAccounts
Customer Accounts (Line 37)
15,493,662
59
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational (Line 38)
1,431
60
SalariesAndWagesGasSales
Sales (Line 39)
700,085
61
SalariesAndWagesGasAdministrativeAndGeneral
Administrative and General (Lines 40 and 49)
5,002,814
62
SalariesAndWagesGasOperationAndMaintenance
TOTAL Operation and Maint. (Total of lines 52 thru 61)
63,940,538
1,769,529
65,710,067
63
SalariesAndWagesOtherUtilityDepartmentsAbstract
Other Utility Departments
64
SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance
Operation and Maintenance
65
SalariesAndWagesOperationsAndMaintenance
TOTAL All Utility Dept. (Total of lines 28, 62, and 64)
218,007,482
6,033,271
224,040,753
66
SalariesAndWagesUtilityPlantAbstract
Utility Plant
67
SalariesAndWagesUtilityPlantConstructionAbstract
Construction (By Utility Departments)
68
SalariesAndWagesUtilityPlantConstructionElectricPlant
Electric Plant
59,339,449
1,642,196
60,981,645
69
SalariesAndWagesUtilityPlantConstructionGasPlant
Gas Plant
16,215,978
448,771
16,664,749
70
SalariesAndWagesUtilityPlantConstructionOther
Other (provide details in footnote):
71
SalariesAndWagesUtilityPlantConstruction
TOTAL Construction (Total of lines 68 thru 70)
75,555,427
2,090,967
77,646,394
72
SalariesAndWagesPlantRemovalAbstract
Plant Removal (By Utility Departments)
73
SalariesAndWagesPlantRemovalElectricPlant
Electric Plant
4,029,256
4,029,256
74
SalariesAndWagesPlantRemovalGasPlant
Gas Plant
1,091,751
1,091,751
75
SalariesAndWagesPlantRemovalOther
Other (provide details in footnote):
76
SalariesAndWagesPlantRemoval
TOTAL Plant Removal (Total of lines 73 thru 75)
5,121,007
5,121,007
77
SalariesAndWagesOtherAccountsAbstract
Other Accounts (Specify, provide details in footnote):
78
SalariesAndWagesOtherAccountsDescription
Other Balance Sheet Accounts
19,803,937
19,803,937
79
SalariesAndWagesOtherAccountsDescription
Other Accounts (Specify, provide details in footnote):
4,968,127
4,968,127
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
24,772,064
24,772,064
96
SalariesAndWagesGeneralExpense
TOTAL SALARIES AND WAGES
323,455,980
8,124,238
331,580,218


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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)
17,207,436
33,766,011
48,312,367
55,585,496
2.1 Net Purchases (Account 555.1)
3 Net Sales (Account 447)
47,578,371
97,051,283
141,557,577
236,132,573
4 Transmission Rights
3,232,760
9,063,790
13,187,487
17,880,502
5 Ancillary Services
737,627
1,094,059
1,749,395
2,514,076
6 Other Items (list separately)
7
Demand
9,585
16,722
16,722
16,722
8
Fees
196,921
414,238
620,553
865,505
9
Transmission Services
1,655,538
3,375,048
5,695,585
7,348,166
10
RSG/Price Volatility Make Whole Pymts
165,899
2,119,996
4,148,647
4,518,987
11
Revenue Neutrality Uplift
311,607
3,081,769
4,023,628
5,836,657
46 TOTAL
34,169,392
73,237,318
109,866,631
201,061,772


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
9,312
MW
175,840
2
Reactive Supply and Voltage
9,312
MW
951,686
2,109,956
MW
1,880,404
3
Regulation and Frequency Response
26,312,313
MWh
1,470,410
126,925
MWh
806,076
4
Energy Imbalance
1,024,877
741,259
5
Operating Reserve - Spinning
26,487,567
MWh
1,302,204
231,672
MWh
1,051,730
6
Operating Reserve - Supplement
26,488,953
MWh
604,262
2,812,258
MWh
1,723,665
7
Other
MWh
70,964
8
Total (Lines 1 thru 7)
79,307,457
5,529,279
5,280,811
6,274,098


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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: 0
1
January
4,379
15
1,900
4,036
343
2
February
4,109
6
800
3,792
317
3
March
3,683
5
1,900
3,412
271
4
Total for Quarter 1
11,240
931
5
April
3,748
6
1,200
3,462
286
6
May
4,890
29
1,500
4,472
419
7
June
5,281
18
1,600
4,848
432
8
Total for Quarter 2
12,782
1,137
9
July
5,512
12
1,600
5,051
460
10
August
5,120
9
1,600
4,695
425
11
September
5,078
17
1,600
4,650
428
12
Total for Quarter 3
14,396
1,313
13
October
4,014
3
1,700
3,676
338
14
November
4,035
26
1,800
3,718
317
15
December
4,015
10
900
3,705
309
16
Total for Quarter 4
11,099
964
17
Total
49,517
4,345


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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: Enter System
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 Year to Date/Year


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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)
(a)(b)(c)
25,927,688
3
Steam
(d)
15,809,377
23
Requirements Sales for Resale (See instruction 4, page 311.)
4
Nuclear
(e)
3,868,644
24
Non-Requirements Sales for Resale (See instruction 4, page 311.)
(f)
11,180,851
5
Hydro-Conventional
(g)
13,945
25
Energy Furnished Without Charge
6
Hydro-Pumped Storage
26
Energy Used by the Company (Electric Dept Only, Excluding Station Use)
29,241
7
Other
(h)
14,275,831
27
Total Energy Losses
744,016
8
Less Energy for Pumping
27.1
Total Energy Stored
9
Net Generation (Enter Total of lines 3 through 8)
(i)
33,967,797
28
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES
37,804,680
10
Purchases (other than for Energy Storage)
(j)
3,836,883
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
(k)
1,209,658
17
Delivered
(l)
1,209,658
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)
(m)
37,804,680


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: MegawattHoursSoldSalesToUltimateConsumers

Reconciliation of sales to Ultimate Consumers (in mWhs)

Sales per page 301, line 10, column (d) 25,927,688

less: Illinois distribution only sales (77,116)

Sales per page 401a, line 22, column (b) 25,850,572

(b) Concept: MegawattHoursSoldSalesToUltimateConsumers
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 22, Column: b, Value: 0
(c) Concept: MegawattHoursSoldSalesToUltimateConsumers
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 22, Column: b, Value: 25850572
(d) Concept: SteamGeneration
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 3, Column: b, Value: 0
(e) Concept: NuclearGeneration
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 4, Column: b, Value: 0
(f) Concept: MegawattHoursSoldNonRequirementsSales
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 24, Column: b, Value: 0
(g) Concept: HydroConventionalGeneration
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 5, Column: b, Value: 0
(h) Concept: OtherEnergyGeneration
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 7, Column: b, Value: 0
(i) Concept: NetEnergyGeneration
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 9, Column: b, Value: 0
(j) Concept: MegawattHoursPurchasedOtherThanStorage
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 10, Column: b, Value: 0
(k) Concept: ElectricPowerWheelingEnergyReceived
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 16, Column: b, Value: 0
(l) Concept: ElectricPowerWheelingEnergyDelivered
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 17, Column: b, Value: 0
(m) Concept: SourcesOfEnergy
Duplicate fact discrepancy. Schedule: 401a - Schedule - Electric Energy Account, Row: 20, Column: b, Value: 0

Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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: 0
29
January
3,364,588
1,029,620
4,036
15
30
February
2,773,494
721,530
3,792
6
31
March
2,900,653
813,381
3,412
5
32
April
2,840,641
829,323
3,462
6
33
May
2,933,705
744,104
4,472
29
34
June
3,264,818
880,875
4,848
18
35
July
3,009,881
616,048
5,051
12
36
August
3,184,734
560,091
4,695
9
37
September
3,111,171
983,701
4,650
17
38
October
3,333,601
1,288,940
3,676
3
39
November
3,489,043
1,336,832
3,718
26
40
December
3,598,353
1,376,407
3,705
10
41
Total


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: HourOfMonthlyPeak
Original value: 19:00
(b) Concept: HourOfMonthlyPeak
Original value: 8:00
(c) Concept: HourOfMonthlyPeak
Original value: 19:00
(d) Concept: HourOfMonthlyPeak
Original value: 12:00
(e) Concept: HourOfMonthlyPeak
Original value: 15:00
(f) Concept: HourOfMonthlyPeak
Original value: 16:00
(g) Concept: HourOfMonthlyPeak
Original value: 16:00
(h) Concept: HourOfMonthlyPeak
Original value: 16:00
(i) Concept: HourOfMonthlyPeak
Original value: 16:00
(j) Concept: HourOfMonthlyPeak
Original value: 17:00
(k) Concept: HourOfMonthlyPeak
Original value: 18:00
(l) Concept: HourOfMonthlyPeak
Original value: 9:00

Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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:
Coralville
Plant Name:
Electrifarm
Plant Name:
Greater Des Moines
Plant Name:
(a)
Louisa
Plant Name:
Merl Parr
Plant Name:
Moline
Plant Name:
(b)
Neal #3
Plant Name:
(c)
Neal #4
Plant Name:
(d)
Ottumwa
Plant Name:
Pleasant Hill
Plant Name:
(e)
Quad-Cities
Plant Name:
River Hills
Plant Name:
Riverside
Plant Name:
Sycamore
Plant Name:
(f)
Walter Scott #3
Plant Name:
(g)
Walter Scott #4
1
PlantKind
Kind of Plant (Internal Comb, Gas Turb, Nuclear)
Gas Trubine
Gas Turbine
Gas Turbine
(h)
Steam
Gas Turbine
Gas Trubine
Steam
Steam
Steam
Gas Turbine
Nuclear
(i)
Gas Turbine
Steam
Gas Turbine
Steam
Steam
2
PlantConstructionType
Type of Constr (Conventional, Outdoor, Boiler, etc)
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
Conventional
3
YearPlantOriginallyConstructed
Year Originally Constructed
1970
1975
2003
1983
1969
1970
1975
1979
1981
1990
1972
1966
1925
1974
1978
2007
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
1970
1978
2004
1983
1969
1970
1975
1979
1981
1994
1972
1967
1961
1974
1978
2007
5
InstalledCapacityOfPlant
Total Installed Cap (Max Gen Name Plate Ratings-MW)
72
264
576
715
36
72
421
282
419
180
505
128
136
158
574
550
6
NetPeakDemandOnPlant
Net Peak Demand on Plant - MW (60 minutes)
76
192
568
668
34
68
379
266
380
146
473
104
114
136
519
545
7
PlantHoursConnectedToLoad
Plant Hours Connected to Load
123
101
1,530
7,831
24
36
5,727
6,528
7,028
233
8,760
44
65
109
6,865
8,304
8
NetContinuousPlantCapability
Net Continuous Plant Capability (Megawatts)
367
9
NetContinuousPlantCapabilityNotLimitedByCondenserWater
When Not Limited by Condenser Water
66
190
488
660
33
64
367
261
156
471
115
108
150
544
633
10
NetContinuousPlantCapabilityLimitedByCondenserWater
When Limited by Condenser Water
66
190
488
659
33
64
367
261
156
454
115
30
150
544
622
11
PlantAverageNumberOfEmployees
Average Number of Employees
4
20
85
3
58
42
47
2
14
4
63
54
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - KWh
271,000
5,537,500
638,948,000
4,289,900,880
105,800
792,800
1,634,986,000
1,258,943,000
1,827,444,000
12,872,000
3,868,644,250
769,800
1,973,800
4,618,200
3,342,122,610
3,468,345,640
13
CostOfLandAndLandRightsSteamProduction
Cost of Plant: Land and Land Rights
2,596
106,098
1,306,678
3,190,573
888
61,370
697,832
472,723
874,699
402,337
165,168
184,787
7,984
3,834,466
14
CostOfStructuresAndImprovementsSteamProduction
Structures and Improvements
557,355
2,167,947
34,806,304
123,783,875
101,331
778,918
46,135,178
35,987,967
56,116,990
6,455,392
50,930,933
676,987
10,701,835
838,625
115,014,706
101,246,386
15
CostOfEquipmentSteamProduction
Equipment Costs
15,457,106
30,533,293
294,671,938
690,900,673
5,988,206
10,930,165
385,090,343
275,530,126
561,705,681
54,240,197
472,495,242
15,219,234
35,033,994
20,302,912
491,560,662
360,082,158
16
AssetRetirementCostsSteamProduction
Asset Retirement Costs
13,958,244
15,416,396
3,189,605
8,999,322
6,283,637
34,879,861
17
CostOfPlant
Total cost (total 13 thru 20)
16,017,057
32,807,338
330,784,920
831,833,365
6,090,425
11,770,453
447,339,749
315,180,421
627,696,692
60,695,589
523,828,512
16,061,389
52,204,253
21,149,521
645,289,695
461,328,544
18
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 17/5) Including
222.4591
124.2702
574.2794
1,163.4033
169.1785
163.4785
1,062.5647
1,117.6611
1,498.0828
337.1977
1,037.2842
125.4796
383.8548
133.8577
1,124.1981
838.7792
19
OperationSupervisionAndEngineeringExpense
Production Expenses: Oper, Supv, & Engr
18,916
147,461
86,838
1,690,614
18,485
19,840
2,343,975
577,431
772,832
19,066
16,650,863
19,151
228,326
18,796
2,386,708
1,779,654
20
FuelSteamPowerGeneration
Fuel
108,904
853,027
21,981,898
79,850,952
62,096
109,111
28,462,695
21,084,774
40,841,411
1,240,153
23,215,032
81,341
401,264
473,109
44,138,216
46,785,701
21
CoolantsAndWater
Coolants and Water (Nuclear Plants Only)
1,813,702
22
SteamExpensesSteamPowerGeneration
Steam Expenses
2,303,721
2,382,954
1,472,042
3,489,787
5,018,243
514,665
2,426,876
5,002,153
23
SteamFromOtherSources
Steam From Other Sources
24
SteamTransferredCredit
Steam Transferred (Cr)
25
ElectricExpensesSteamPowerGeneration
Electric Expenses
27,684
66,744
1,954,428
670,468
6,464
62,032
91,361
14,678
1,396,380
15,733
99,651
8,184
373,707
7,635
14,163
96,015
26
MiscellaneousSteamPowerExpenses
Misc Steam (or Nuclear) Power Expenses
48,210
105,554
382,788
3,219,581
48,293
167,334
1,917,350
1,119,005
1,364,471
198,595
19,649,709
122,935
220,419
222,005
1,571,811
1,065,883
27
RentsSteamPowerGeneration
Rents
1,953
4,918
336,988
249,377
28
Allowances
Allowances
1
2
20,901
10,568
7,521
2,075
1
14
19,760
3,732
29
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
Maintenance Supervision and Engineering
10,201
10,034
433,332
762,640
9,959
12,084
925,823
1,162,996
564,623
87,074
13,323,939
45,191
14,477
49,887
1,131,835
649,477
30
MaintenanceOfStructuresSteamPowerGeneration
Maintenance of Structures
354
8,399
216,583
403,755
856
11,258
1,531,457
181,918
201,205
29,471
2,033,916
8,893
65,491
10,703
1,506,595
425,879
31
MaintenanceOfBoilerPlantSteamPowerGeneration
Maintenance of Boiler (or reactor) Plant
5,378,042
8,610,750
2,558,525
3,093,138
2,931,046
211,315
8,141,482
1,800,981
32
MaintenanceOfElectricPlantSteamPowerGeneration
Maintenance of Electric Plant
123,380
503,417
2,958,279
2,673,536
12,075
166,241
1,790,197
324,978
223,655
345,727
3,995,069
235,607
243,137
150,043
1,499,303
1,108,758
33
MaintenanceOfMiscellaneousSteamPlant
Maintenance of Misc Steam (or Nuclear) Plant
323
71,590
100,513
954,878
11,687
17,954
635,695
410,608
1,071,688
63,005
2,966,884
80,309
69,868
139,750
1,349,075
1,467,113
34
PowerProductionExpensesSteamPower
Total Production Expenses
337,972
1,766,225
28,114,661
97,929,088
169,915
565,854
48,700,872
28,919,394
53,021,265
1,998,823
91,698,054
601,611
2,342,669
1,071,914
63,848,836
60,434,723
35
ExpensesPerNetKilowattHour
Expenses per Net KWh
1.2471
0.319
0.044
0.0228
1.606
0.7137
0.0298
0.023
0.029
0.1553
0.0237
0.7815
1.1869
0.2321
0.0191
0.0174
35
FuelKindAxis
Plant Name
Coralville
Coralville
Coralville
Electrifarm
Electrifarm
Electrifarm
Greater Des Moines
Greater Des Moines
Greater Des Moines
Louisa
Louisa
Louisa
Merl Parr
Merl Parr
Merl Parr
Moline
Moline
Moline
Neal #3
Neal #3
Neal #3
Neal #4
Neal #4
Neal #4
Ottumwa
Ottumwa
Ottumwa
Pleasant Hill
Pleasant Hill
Pleasant Hill
Quad-Cities
Quad-Cities
River Hills
River Hills
River Hills
Riverside
Riverside
Riverside
Sycamore
Sycamore
Sycamore
Walter Scott #3
Walter Scott #3
Walter Scott #3
Walter Scott #4
Walter Scott #4
Walter Scott #4
36
FuelKind
Fuel Kind
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
Nuclear
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
Coal
Gas
Oil
37
FuelUnit
Fuel Unit
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Grams
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
Tons
MCF
Bbl.
38
QuantityOfFuelBurned
Quantity (Units) of Fuel Burned
24,365
119,354
4,598,890
2,472,727
166,274
7
9,776
26,699
942,106
100,514
693,386
14,529
1,146,702
9,239
223,666
364,533
15,460
90,381
99,995
282
1,916,251
19,538
1,840,523
30,507
13,479
39
FuelBurnedAverageHeatContent
Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
1,059,145
1,057,662
1,056,421
8,510
1,051,614
138,298
1,065,330
1,052,797
8,611
1,055,475
8,684
137,304
8,487
90,610
1,055,502
116,107,638
1,060,220
1,057,576
1,058,953
8,746
136,000
8,721
945,226
136,003
40
AverageCostOfFuelPerUnitAsDelivered
Avg Cost of Fuel/unit, as Delvd f.o.b. during year
4.47
7.147
4.78
32.345
4.486
6.352
4.087
30.281
6.241
29.857
92.406
31.783
100.04
5.545
5.261
4.427
4.622
24.147
90.232
23.995
5.027
93,530
41
AverageCostOfFuelPerUnitBurned
Average Cost of Fuel per Unit Burned
4.47
7.147
4.78
31.991
4.486
164.127
6.352
4.087
29.546
6.241
28.514
90.411
34.774
104.598
5.545
63.684
5.261
4.427
4.622
38.767
22.119
89.746
24.738
5.027
81,658
42
AverageCostOfFuelBurnedPerMillionBritishThermalUnit
Average Cost of Fuel Burned per Million BTU
4.22
6.757
4.525
1.881
4.265
28.196
5.962
3.882
1.716
5.913
1.646
15.678
2.053
27.485
5.253
0.548
4,963
4.186
4.365
6.791
1.264
15.712
1.417
5.318
14,296
43
AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Average Cost of Fuel Burned per KWh Net Gen
0.402
0.154
0.034
0.019
0.587
0.138
0.017
0.017
0.022
0.096
0.006
0.106
0.203
1.02
0.013
0.013
44
AverageBritishThermalUnitPerKilowattHourNetGeneration
Average BTU per KWh Net Generation
95,225
22,797
7,604
10,569
98,437
35,455
10,330
10,358
10,306
18,341
10,941
21,293
48,427
23,278
10,091
9,310


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: PlantName

Louisa Station is jointly owned in the percentages shown below:

 

City of Eldridge 0.500%

City of Geneseo 0.500

City of Tipton 0.500

City of Harlan 0.800

City of Waverly 1.100

Interstate Power and Light Company 4.000

Central Iowa Power Cooperative 4.600

MidAmerican Energy Company 88.000

100.000%

 

Louisa Station is operated by the respondent.

(b) Concept: PlantName

George Neal Station Unit 3 is jointly owned in percentages as shown below:

 

Interstate Power and Light Company 28.000%

MidAmerican Energy Company 72.000

100.000%

 

George Neal Station Unit 3 is operated by the respondent.

(c) Concept: PlantName

George Neal Station Unit 4 is jointly owned in percentages as shown below:

 

Graettinger Municipal Light Plant 0.174%

Grundy Center 0.333

Bancroft Municipal Utilities 0.347

Milford Municipal Utilities 0.347

Coon Rapids Municipal Utilities 0.521

Laurens Municipal Light & Power 0.521

Spencer Municipal Utilities 1.215

Cedar Falls Municipal Utilities 2.500

Webster City Municipal Utilities 2.604

Algona Municipal Utilities 2.937

Northwestern Energy 8.681

Northwest Iowa Power Cooperative 4.860

Corn Belt Power Cooperative 8.695

Interstate Power and Light Company 25.695

MidAmerican Energy Company 40.570

100.000%

 

George Neal Station Unit 4 is operated by the respondent.

(d) Concept: PlantName

Ottumwa Station is jointly owned in the percentages as shown below:

 

Interstate Power and Light Company 48.000%

MidAmerican Energy Company 52.000

100.000%

 

Ottumwa Station is operated by Interstate Power and Light Company.

All on-site employees at Ottumwa Generating Station are Interstate Power and Light employees.

 

 

 

 

(e) Concept: PlantName

Quad-Cities Nuclear Power Station is jointly owned in the percentages shown below:

 

Exelon Generating Company, LLC. 75.000%

MidAmerican Energy Company 25.000

100.000%

 

Quad-Cities Nuclear Power Station Units 1 and 2 are operated by Exelon Generating Company, LLC.

All on-site employees at Quad-Cities Nuclear Power Station are Exelon Generating employees.

(f) Concept: PlantName

Walter Scott, Jr. Energy Center Unit 3 is jointly owned in the percentages as shown below:

 

Atlantic Municipal Utilities 2.500%

Cedar Falls Municipal Utilities 3.100

Corn Belt Power Cooperative 3.800

Central Iowa Power Cooperative 11.500

MidAmerican Energy Company 79.100

100.000%

 

Walter Scott, Jr. Energy Center Unit 3 is operated by the respondent.

Walter Scott, Jr. Energy Center was renamed in July 2007 and previously known as Council Bluffs Energy Center.

(g) Concept: PlantName

Walter Scott, Jr. Energy Center Unit 4 is jointly owned in the percentages as shown below:

 

West Bend Municipal Utilities 0.140%

Sumner Municipal Light Plant 0.140

Alta Municipal Power Plant 0.140

Waverly Light & Power 0.400

Montezuma Municipal Light & Power 0.420

New Hampton Municipal Light Plant 0.560

Eldgridge Electric & Water Utilities 0.530

Spencer Municipal Utilities 1.140

Cedar Falls Municipal Utilities 2.140

Corn Belt Power Cooperative 5.600

Municipal Energy Agency of Nebraska 6.920

Central Iowa Power Cooperative 9.550

Lincoln Electric System 12.660

MidAmerican Energy Company 59.660

100.000%

 

Walter Scott, Jr. Energy Center Unit 4 is operated by the respondent.

Walter Scott, Jr. Energy Unit 4 jointly owned ownership allocation changed November 1, 2011 due to the sale of Pella's share.

Walter Scott, Jr. Energy Center was renamed in July 2007 and previously known as Council Bluffs Energy Center.

(h) Concept: PlantKind

Plant hours connected to load is an average of service hours of all units.

Data for the jointly-owned units reported on pages 402 through 403 is the respondent's portion only.

(i) Concept: PlantKind

Gas Turbine units are designed for peak load service and are automatically operated.

Plant hours connected to load is a sum of service hours of all units for peaking facilities.

(j) Concept: AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Duplicate fact discrepancy. Schedule: 402 - Schedule - Steam-Electric Generating Plant Statistics (Large Plants) - Fuel Statistics, Row: 14, Column: 43, Value: 0
(k) Concept: AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Duplicate fact discrepancy. Schedule: 402 - Schedule - Steam-Electric Generating Plant Statistics (Large Plants) - Fuel Statistics, Row: 15, Column: 43, Value: 0
(l) Concept: AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Duplicate fact discrepancy. Schedule: 402 - Schedule - Steam-Electric Generating Plant Statistics (Large Plants) - Fuel Statistics, Row: 10, Column: 43, Value: 0
(m) Concept: AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Duplicate fact discrepancy. Schedule: 402 - Schedule - Steam-Electric Generating Plant Statistics (Large Plants) - Fuel Statistics, Row: 9, Column: 43, Value: 0
(n) Concept: AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Duplicate fact discrepancy. Schedule: 402 - Schedule - Steam-Electric Generating Plant Statistics (Large Plants) - Fuel Statistics, Row: 11, Column: 43, Value: 0
(o) Concept: AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Duplicate fact discrepancy. Schedule: 402 - Schedule - Steam-Electric Generating Plant Statistics (Large Plants) - Fuel Statistics, Row: 12, Column: 43, Value: 0
(p) Concept: AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Duplicate fact discrepancy. Schedule: 402 - Schedule - Steam-Electric Generating Plant Statistics (Large Plants) - Fuel Statistics, Row: 7, Column: 43, Value: 0
(q) Concept: AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Duplicate fact discrepancy. Schedule: 402 - Schedule - Steam-Electric Generating Plant Statistics (Large Plants) - Fuel Statistics, Row: 13, Column: 43, Value: 0
(r) Concept: AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Duplicate fact discrepancy. Schedule: 402 - Schedule - Steam-Electric Generating Plant Statistics (Large Plants) - Fuel Statistics, Row: 8, Column: 43, Value: 0

Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Moline Conventional Hydro (4 units @ 900KW each)
1941
3.6
3
13,945,400
2,968,274
824,521
48,166
98,189
2
(Amounts are for the total of all 4 units)
4
Portable Power Modules (28 units @ 2 MW each)
2000
56
41
401,906
23,709,309
423,381
24,506
70,417
717,397
Diesel Oil
17
5
(Amounts are for the total of all 28 units)
7
Intrepid Wind Farm (107 units @ 1.5 MW each &
2004
175.5
173
488,239,370
285,278,384
1,625,518
697,221
4,443,536
8
15 units @ 1 MW each)
9
(Amounts are for the total of all 122 units)
11
Century Wind Farm (100 units @ 1.5 MW each &
2005
201.2
199
529,756,325
320,999,944
1,595,427
1,028,511
5,345,786
12
10 units @ 1.62 MW each & 35 units @ 1 MW each)
13
(Amounts are for the total of all 145 units)
15
Victory Wind Farm (16 units @1.5 MW each
2006
105
100
364,440,990
183,463,303
1,747,270
428,235
2,312,172
16
and 50 units @ 1.62 MW each)
17
(Amounts are for the total of all 66 units)
19
State Fair Wind Turbine (1 unit @ .5 MW each)
2007
0.5
0.2
93,504
935,871
1,871,742
9,499
11,941
21
Pomeroy Wind Farm (137 units @ 1.5 MW each &
2007
290.48
285
711,269,020
651,415,119
2,242,547
1,077,959
5,218,825
22
34 units @ 1.62 MW & 13 units @ 2.3 MW each)
23
(Amounts are for the total of all 184 units)
25
Charles City Wind Farm (8 units @ 1.5 MW each &
2008
80.04
76
206,112,560
220,186,099
2,750,951
312,443
1,374,500
26
42 units @ 1.62 MW each)
27
(Amounts are for the total of all 50 units)
29
Adair Wind Farm (76 units @ 2.3 MW each)
2008
174.8
171
414,150,430
366,856,076
2,098,719
697,489
4,269,423
30
(Amounts are for the total of all 76 units)
32
Carroll Wind Farm (100 units @ 1.5 MW each)
2008
150
148
434,528,380
303,478,157
2,023,188
634,238
2,315,628
33
(Amounts are for the total of all 100 units)
35
Walnut Wind Farm (102 units @ 1.5 MW each)
2008
153
151
431,516,120
346,018,195
2,261,557
612,494
2,149,023
36
(Amounts are for the total of all 102 units)
38
Rolling Hills Wind Farm (193 units @ 2.3MW each)
2011
443.9
431
1,186,958,900
719,018,218
1,619,775
1,936,589
10,602,677
39
(Amounts are for the total of all 193 units)
41
Laurel Wind Farm (52 units @ 2.3 MW each)
2011
119.6
117
334,861,520
207,330,278
1,733,531
845,102
2,933,719
42
(Amounts are for the total of all 52 units)
44
Eclipse Wind Farm (87 units @ 2.3 MW each)
2012
200.1
197
638,891,800
331,874,654
1,658,544
657,483
4,841,099
45
(Amounts are for the total of all 87 units)
102
Morning Light Wind Farm (44 units @ 2.3 MW each)
2012
101.2
98
312,507,800
157,707,217
1,558,372
367,789
2,556,955
103
(Amounts are for the total of all 44 units)
105
Vienna Wind Farm (64 units @ 2.346 MW each)
2012
150.14
147
440,954,500
241,588,019
1,609,042
953,609
3,978,436
106
(Amounts are for the total of all 64 units)
108
Lundgren Wind Farm (107 units @ 2.346 MW each)
2014
251.02
245
795,965,400
393,013,400
1,565,653
1,363,807
4,990,550
109
(Amounts are for the total of all 107 units)
111
Macksburg Wind Farm (51 units @ 2.346 MW each)
2014
119.65
117
340,761,900
199,791,636
1,669,856
684,663
2,550,218
112
(Amounts are for the total of all 51 units)
114
Wellsburg Wind Farm (60 units @ 2.346 MW each)
2014
140.76
138
431,123,000
244,768,232
1,738,905
919,738
2,834,153
115
(Amounts are for the total of all 60 units)
117
Highland Wind Farm (214 units @ 2.346 MW each)
2015
502.04
478
1,545,240,220
820,329,807
1,633,980
3,022,670
10,037,495
118
(Amounts are for the total of all 214 units)
120
Adams Wind Farm (60 units @ 2.415 MW each &
2015
154.28
151
459,959,730
230,932,888
1,496,804
842,368
2,936,847
121
4 units @ 2.346 MW each)
122
(Amounts are for the total of all 64 units)
124
Ida Grove Wind Farm (14 units @ 1.79 MW each &
2016
301.06
300
1,129,072,260
498,864,638
1,657,027
2,123,453
6,805,132
125
120 units @ 2.30 MW each)
126
(Amounts are for the total of all 134 units)
128
O'Brien Wind Farm (13 units @ 2.346 MW each &
2016
250.26
244
814,575,800
373,253,657
1,491,446
1,402,588
4,729,314
129
91 units @ 2.415 MW each)
130
(Amounts are for the total of all 104 units)
132
Prairie Wind Farm (84 units @ 2.0 MW each)
2017
168
165
546,328,890
256,008,681
1,523,861
978,310
3,707,716
133
(Amounts are for the total of all 84 units)
135
Beaver Creek Wind Farm
2017
340
333
812,153,180
510,560,365
1,501,648
1,460,297
5,155,461
136
(170 units @ 2.0 MW each)
137
(Amounts are for the total of all 170 units)
139
Arbor Hill Wind Farm (125 units @ 2.0 MW each)
2018
250
232
75,958,380
381,467,676
1,525,871
246,274
502,609
140
(Amounts are for the total of all 125 units)
142
North English Wind Farm
2018
200
188
141,274,100
496,507,710
2,482,539
5,568
803,377
143
(100 units @ 2.0 MW each)
144
(Amounts are for the total of all 100 units)
201
Ivester Wind Farm (30 units @ 2.625 MW each &
2018
90.83
64
10,232,100
121,894,689
1,342,083
597
41,488
202
5 units @ 2.415 MW each)
203
(Amounts are for the total of all 35 units)
205
Orient Wind Farm (51 units @ 2.0 MW each)
2018
102
92
16,127,200
39,274,790
385,047
473
50,647
206
(Amounts are for the total of all 51 units)


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Sycamore
Bondurant
345
345
9.38
1
853 ACAR 24/13
90,400
1,583,912
1,674,312
2
Booneville
MO State Line
345
345
95.95
1
853 ACAR 24/13
1,056,785
15,248,441
16,305,226
3
Grimes North
(a)
Beaver Creek
345
345
43.4
1
795 ACSR/2-853
735,278
7,406,380
8,141,658
4
Sycamore North
(b)
Grimes North
345
345
7.64
2
795 ACSR 26/7
129,436
949,255
1,078,691
5
Beaver Creek
(c)
Lehigh
345
345
18.3
2
795 ACSR/2-853
310,036
1,565,627
1,875,663
6
Grimes South
(d)
Sycamore South
345
345
7.64
1
2-853.7 ACAR
14,338
935,358
949,696
7
E. Pony Creek Tap
(e)
W. Rolling H Tap
345
345
53.09
1
795 ACSR 26/7
1,197,203
5,335,672
6,532,875
8
E. Pony Creek Tie
E. Pony Creek Tap
345
345
0.39
1
T2-397 ACSR 26/7
902,990
902,990
9
CBEC
(f)
W. Pony Creek Tap
345
345
2.41
1
795 ACSR 26/7
54,347
215,587
269,934
10
W. Pony Creek Tie
W. Pony Creek Tap
345
345
0.4
1
T2-397 ACSR 26/7
750,390
750,390
11
East Rolling Hills Tap
(g)
Madison County
345
345
55.71
1
795 ACSR 26/7
1,256,285
6,748,420
8,004,705
12
West Rolling HIlls Tap
Rolling HIlls
345
345
0.05
1
795 ACSR 26/7
283,381
283,381
13
East Rolling Hills Tap
Rolling Hills
345
345
0.05
1
795 ACSR 26/7
611,908
611,908
14
Madison County
(h)
Booneville
345
345
13.15
1
795 ACSR 26/7
296,537
1,454,373
1,750,910
15
Sub 93
(i)
Sub 39
345
345
47.54
1
954 ACSR 54/7
2,229,772
12,223,283
14,453,055
16
Sub 93
(j)
Sub 92
345
345
23.92
1
795 ACSR 26/7
967,274
6,272,593
7,239,867
17
Sub 93
(k)
Sub T
345
345
25.64
1
795 ACSR 26/7
1,111,637
5,219,044
6,330,681
18
CBEC
(l)
NE State Line
345
345
6.16
1
954 ACSR 54/7
28,417
671,464
699,881
19
DAEC
Hazelton
345
345
18.11
1
795 ACSR 26/7
108,633
1,794,669
1,903,302
20
Montezuma
Hills
345
345
53.6
1
853 ACAR 24/13
452,731
6,969,888
7,422,619
21
Sub 39
MEC Cordova Sub
345
345
15.45
1
954 ACSR 54/7
375,377
1,661,322
2,036,699
22
QCPS
MEC Cordova Sub
345
345
2.23
1
2338ACAR954ACSR
23
Hills
DAEC (Str D-608)
345
345
28.66
1
795 ACSR 26/7
24,867
2,205,110
2,229,977
24
Raun
(m)
Neal 4
345
345
2.12
2
795 ACSR 26/7
386,957
386,957
25
Sub 56
Walcott
345
345
6.38
1
954 ACSR 54/7
13,461
591,649
605,110
26
Raun
(n)
WAPA Sioux City
345
345
23.59
2
954 ACSR 54/7
89,145
3,023,490
3,112,635
27
Raun
NE State Line (OPPD)
345
345
1.08
1
954 ACSR 54/7
21,444
230,377
251,821
28
OGS
(o)
Montezuma
345
345
36.4
1
795 ACSR 26/7
521,138
14,251,714
14,772,852
29
Raun
Highland
345
345
62.75
1
795 ACSR 26/7
169,566
4,407,238
4,576,804
30
Highland
O'Brien
345
345
11.85
1
795 ACSR 26/7
32,048
832,956
865,004
31
O'Brien
MN State Line
345
345
24.25
1
795 ACSR 26/7
65,672
1,706,902
1,772,574
32
Raun
(p)
Neal North
345
345
0.78
1
795 ACSR 26/7
168,207
168,207
33
Sub 56
Sub 91
345
345
13.37
1
954 ACSR 54/7
389,182
2,892,224
3,281,406
34
Sub 91
QCPS
345
345
13.63
1
954 ACSR 54/7
390,610
1,097,704
1,488,314
35
Raun
(q)
Ida County
345
345
47.73
3.49
2
795&T2-397 ACSR
950,802
7,088,135
8,038,937
36
Ida County
(r)
Lehigh
345
345
64.94
1
795&T2-397 ACSR
1,200,038
8,865,899
10,065,937
37
Lehigh
(s)
Webster
345
345
14.49
2
795 ACSR 26/7
234,345
2,178,513
2,412,858
38
Overland Trail
(t)
Fallow Ave Sub
345
345
68.65
1
T2-556 ACSR
3,641,584
43,042,425
46,684,009
39
CBEC4
(u)
Overland Trail
345
345
2.74
2
T2-556 ACSR 26/7
1,110,729
1,110,729
40
Fallow Ave Sub
(v)
Grimes
345
345
52.67
1
T2-556 ACSR
3,504,648
32,003,327
35,507,975
41
Grimes South
(w)
Booneville
345
345
16.71
2
T2-556 ACSR
1,551,727
6,829,480
8,381,207
42
SE Polk
GDMEC
345
345
1.28
1
T2-397 ACSR 26/7
18,007
1,217,421
1,235,428
43
GDMEC
Bondurant
345
345
8.66
2
T2-397 ACSR 26/7
453,368
8,771,170
9,224,538
44
Raun
NE State Line (NPPD)
345
345
1.08
1
954 ACSR 54/7
15,523
1,151,058
1,166,581
45
Sub 92
Hills
345
345
16.32
1
954 ACSR 54/7
156,871
1,755,391
1,912,262
46
Adams (STR B330)
Hazelton (STR B255)
345
345
15.94
1
795 ACSR 26/7
22,146
22,146
47
Bondurant
Montezuma
345
345
49.9
1
853 ACAR 24/13
409,897
4,736,807
5,146,704
48
Walcott
Sub 92
345
345
21.5
1
954 ACSR 54/7
185,025
2,148,335
2,333,360
49
Madison City Sw Sta
Norwalk
345
345
14.62
2
T2-397 ACSR 26/7
58,713
10,220,821
10,279,534
50
Norwalk
S.E. Polk
345
345
10.02
2
T2-397 ACSR 26/7
40,190
7,165,509
7,205,699
51
IA State Line
Cooper
345
345
23.54
1
853 ACAR 24/13
36,110
1,009,342
1,045,452
52
MVP-Blackhawk
Hazelton (Str BE66)
345
345
11.98
1
T2-556 ACSR 26/7
1,085,593
17,678,330
18,763,923
53
Pony Creek
Southland West
345
345
0.17
1
T2-556 ACSR 26/7
1,333,227
1,333,227
54
CBEC
Southland
345
345
2.92
1
T2-556 ACSR 26/7
25,814
10,675,468
10,701,282
55
Pony Creek
Southland East
345
345
0.14
1
T2-556 ACSR 26/7
1,266,228
1,266,228
56
O'Brien
Kossuth
345
345
74.1
2
T2-556 ACSR 26/7
6,540,663
127,058,337
133,599,000
57
Kossuth
Webster
345
345
46.64
2
T2-556 ACSR 26/7
3,086,503
85,099,318
88,185,821
58
Oak Grove
Mercer
345
345
14.76
2
T2-556 ACSR 26/7
25,220
28,168,268
28,193,488
59
Mercer
Sandburg
345
345
17.73
2
T2-556 ACSR 26/7
59,039
29,560,240
29,619,279
60
Blackhawk
Hampton
345
345
59.07
2
T2-556 ACSR 26/7
5,542,347
105,025,194
110,567,541
61
Less non-MEC 345 kV partial
62
ownership miles
179.86
7.55
63
345 kV Expenses
1,268,993
162,476
151,913
1,583,382
64
Raun
Morningside
161
161
12.43
1
556 ACSR 24/7
255,260
2,304,565
2,559,825
65
Morningside
Plymouth
161
161
11.17
1
556 &T2 397 ACSR
27,963
843,817
871,780
66
Johnston
Sycamore
161
161
3.08
2
1192 AL 61 STR
56,618
2,310,828
2,367,446
67
100th St. & 54th Ave.
Johnston
161
161
2.49
2
1192 AL 61 STR
45,766
2,097,305
2,143,071
68
Clarinda
Brooks
161
161
23
1
397 ACSR 26/7
19,479
1,429,646
1,449,125
69
Idaho Avenue
Creston
161
161
21.39
1
397 ACSR 26/7
38,957
2,093,611
2,132,568
70
Butler
Blackhawk
161
161
24.34
1
477 ACSR 26/7
78,842
993,496
1,072,338
71
Earlham
Booneville
161
161
14.56
2
T2-556 ACSR
86,922
5,579,673
5,666,595
72
Franklin
Butler
161
161
26.39
1
T2-556 ACSR
84,930
3,029,887
3,114,817
73
Sub 28
Sub 17
161
161
10.73
1
795 ACSR 26/7
59,016
550,984
610,000
74
Booneville
West Grand
161
161
5.49
1
2156 ACSR 84/19
34,732
139,208
173,940
75
West Grand
60th St.
161
161
2.25
1
2156 ACSR 84/19
13,122
399,844
412,966
76
60th St.
Ashawa
161
161
2.21
1
2156 ACSR 84/19
13,359
580,433
593,792
77
Sub 56
Sub 89
161
161
22.15
1
795 ACSR 26/7
49,476
1,411,740
1,461,216
78
Hastings
Bunge
161
161
20.26
1
397 ACSR 26/7
53,147
363,664
416,811
79
CBEC-River Bend
River Bend-Bunge
161
161
2.32
1
397 ACSR 26/7
5,833
1,430,748
1,436,581
80
Sub 39
Sub 31 Tap
161
161
5.66
1
795 ACSR 26/7
31,130
291,999
323,129
81
Greenfield Plaza
SE Polk
161
161
0.9
6.59
2
556 ACSR 26/7
144,920
2,812,880
2,957,800
82
Altoona-Metro East
DMEC
161
161
6.48
1
T2-556 ACSR 26/7
110,802
3,564,917
3,675,719
83
Sub 702
Sub 701
161
161
1.89
2
1192 AL 61 STR
8,810
572,543
581,353
84
Sub 701
NE State Line (OPPD)
161
161
6.71
2
1192 AL 61 STR
31,292
1,703,875
1,735,167
85
Clarinda
Hastings
161
161
31.27
1
397 ACSR 26/7
84,295
1,641,681
1,725,976
86
Wright
Wall Lake
161
161
11.68
1
477/1192 ACSR
35,688
190,944
226,632
87
Wall Lake
Franklin
161
161
17.72
1
477/1192 ACSR
55,182
820,692
875,874
88
Newport
(x)
Denmark
161
161
11.3
1
556 ACSR 26/7
19,060
288,181
307,241
89
Sub 17
Sub 49
161
161
3.53
1
T2-397 ACSR 26/7
33,638
1,410,514
1,444,152
90
Washburn
Hazelton
161
161
28.53
1
636 ACSR 26/7
69,371
3,546,877
3,616,248
91
Sac
Pocahontas
161
161
27.12
1
T2-556 ACSR 26/7
112,615
8,157,999
8,270,614
92
Pocahontas
Pomeroy
161
161
4.93
1
477 ACSR 26/7
17,415
148,568
165,983
93
SE Polk
DMEC (West Line)
161
161
0.99
1
T2-556 AL 37 STR
125,470
125,470
94
DMEC
Reasnor
161
161
23.87
1
397 ACSR 26/7
32,303
5,514,810
5,547,113
95
SE Polk
DMEC (East Line)
161
161
0.93
1
T2-556 ACSR 26/7
5,693
22,817
28,510
96
100th & Douglas
109th & Clark
161
161
2.43
1
1192 AL 61 STR
53,206
615,589
668,795
97
Webster
Wright
161
161
11.77
1
477 ACSR 26/7
36,808
548,333
585,141
98
Sub 49
IPW Tie (Beaver Chnl)
161
161
4.77
1
795 &T2-397 ACSR
35,138
2,490,663
2,525,801
99
100th St & 54th Ave
100th & Douglas
161
161
3.9
1
1192 AL 61 STR
85,305
1,130,789
1,216,094
100
Plymouth
LeMars South Tap
161
161
9.03
1
477 ACSR 26/7
33,622
820,877
854,499
101
LeMarks South Tap
Little Sioux
161
161
31.05
1
477 ACSR 26/7
105,670
1,248,081
1,353,751
102
Sub 31 Tap
Sub 28
161
161
0.66
1
795 ACSR 26/7
3,630
34,050
37,680
103
Neal 4
Monona
161
161
32.26
1
636 ACSR 26/7
144,810
2,501,493
2,646,303
104
Sub 89
Hills
161
161
28.76
1
795 ACSR 26/7
64,269
1,775,775
1,840,044
105
Boone Jct
Sub T (Ft. Dodge)
161
161
13.24
1
397 ACSR 26/7
49,542
446,916
496,458
106
Raun
Neal 4
161
161
2.12
1
795 ACSR 26/7
8,456
62,837
71,293
107
Wisdom
Triboji (Str 93)
161
161
12.56
1
636 ACSR 26/7
46,271
262,481
308,752
108
Altoona
Bondurant
161
161
2.13
1
T2-556 ACSR 26/7
35,705
1,121,529
1,157,234
109
SE Polk AF Term
SE Polk AB Term
161
161
0.04
1
T2-556 AL 37 STR
5,342
5,342
110
Sub 18
Sub 43
161
161
8.88
1
1192 ACSR 54/19
166,503
2,447,069
2,613,572
111
Raun
Neal North (North Tie)
161
161
0.62
1
1192 ACSR 45/7
1,091
8,297
9,388
112
Bondurant
Sycamore
161
161
10.43
1
1192 ACSR 45/7
156,547
5,686,460
5,843,007
113
Sub T
Webster
161
161
14.23
1
477 ACSR 26/7
31,471
201,389
232,860
114
Atlantic Munic Tap E
Adair-Earlham
161
161
42.12
1
T2-556 ACSR 26/7
275,458
1,510,435
1,785,893
115
Pomeroy
Hayes
161
161
21.78
1
T2-556/477 ACSR
169,119
7,540,754
7,709,873
116
Sub T
Tate & Lyle
161
161
9.18
1
T2-556/477 ACSR
18,938
2,574,380
2,593,318
117
Hayes Sub
Webster
161
161
14.56
1
636 ACSR 26/7
129,123
2,053,878
2,183,001
118
Hayes
Harvest Avenue
161
161
1.16
1
T2-556 ACSR 26/7
36,010
1,141,790
1,177,800
119
Tate & Lyle
Harvest Avenue
161
161
0.25
1
T2-556 ACSR 26/8
371,778
371,778
120
Avoca-Teakwood
Atlantic Munic Tap W
161
161
17.58
1
T2-556 ACSR 26/7
133,138
605,593
738,731
121
Raun
Neal North (South Tie)
161
161
0.62
1
1192 ACSR 45/7
1,091
8,098
9,189
122
109th & Clark
Ashawa
161
161
3.31
1
1192 AL 61 STR
66,125
904,345
970,470
123
Monona
Crawford County
161
161
16.37
1
636 ACSR 26/7
64,436
1,251,821
1,316,257
124
Crawford County
Victory
161
161
17.19
1
636 ACSR 26/7
67,672
971,243
1,038,915
125
Victory
Carroll
161
161
16.85
1
636 ACSR 26/7
66,066
939,884
1,005,950
126
Little Sioux
Clipper Sub
161
161
17.43
2.62
1
477/1192 ACSR
87,146
6,461,032
6,548,178
127
Clipper Sub
Sac County
161
161
2.99
1
477/1192 ACSR
10,617
121,545
132,162
128
Sub 87
(y)
Newport
161
161
12.69
1
556 ACSR 26/7
20,238
523,103
543,341
129
Winterset Jct.
Creston
161
161
23.76
1
397 ACSR 26/7
33,440
514,662
548,102
130
Sub 18 - Oak Grove
Mercer County
161
161
18.25
1
556 ACSR 26/7
52,044
489,849
541,893
131
Plymouth
WAPA Sioux City
161
161
1.25
1
477 ACSR 26/7
3,665
117,283
120,948
132
Raun
NE State Line (OPPD)
161
161
1.55
1
556 ACSR 24/7
9,635
147,621
157,256
133
Quick Sub
Avoca
161
161
21.3
1
T2-556 ACSR 26/7
127,924
1,219,094
1,347,018
134
Overland Trail
Quick Sub
161
161
9.07
2
T2-556 ACSR 26/7
54,139
750,708
804,847
135
CBEC
Overland Trail
161
161
3.11
2
T2-556 ACSR 26/7
18,426
364,550
382,976
136
Sub 18
Sub 85
161
161
3.84
1
556 ACSR 26/7
23,101
236,977
260,078
137
OGS
(z)
Wapello
161
161
18.88
1
954 ACSR 45/7
147,897
1,450,253
1,598,150
138
Parnell
Powesheik
161
161
33.03
1
397 ACSR 26/7
108,957
1,255,143
1,364,100
139
Winterset Jct.
Norwalk
161
161
4.38
14.25
1
397/T2-556 ACSR
132,218
6,495,566
6,627,784
140
Norwalk
Greenfield Plaza
161
161
0.95
3.47
1
397/T2-556 ACSR
28,678
1,582,602
1,611,280
141
Norwalk
Booneville
161
161
16.88
1
T2-556 ACSR 26/7
1,499,726
8,985,680
10,485,406
142
Sub 85
Sub 56
161
161
7.45
1
556 ACSR 26/7
45,533
2,709,035
2,754,568
143
Sub 18
Oak Grove East (West)
161
161
3.33
2
T2-556 ACSR 26/7
204,242
2,218,479
2,422,721
144
Clarinda
MO State Line (SWPP)
161
161
12.3
1
397 ACSR 26/7
17,053
1,652,793
1,669,846
145
Sub 18 - Sub 112
Sub 87
161
161
26.54
1
556 ACSR 26/7
115,774
1,539,159
1,654,933
146
Floyd
Emery
161
161
36.07
1
636 ACSR 26/7
170,661
974,611
1,145,272
147
Sub 43
Sub 39
161
161
10.42
1
1192 ACSR 54/19
195,379
1,146,180
1,341,559
148
Ashawa
Army Post
161
161
4.24
1
556 ACSR 26/7
24,787
209,019
233,806
149
Army Post
Greenfield Plaza
161
161
5.42
1
556 ACSR 26/7
30,549
4,709,783
4,740,332
150
Ashawa
88th St. D.M.
161
161
4.18
1
T2-556 AL/1192 AL
24,004
1,653,906
1,677,910
151
88th St. Sub
Alice's Road Sub
161
161
3.07
1
T2-556 AL 37 ST
274,504
1,488,426
1,762,930
152
Granger Tap
100th & 54th Sub
161
161
0.97
1
T2-556 AL 37 ST
116,134
361,568
477,702
153
Grimes
(aa)
Granger Tap
161
161
2.3
1
T2-556 AL 37 ST
172,578
619,497
792,075
154
142nd St Sub
Grimes
161
161
1.47
1
T2-556 AL 37 ST
130,587
392,789
523,376
155
Alice's Road Sub
142nd St Sub
161
161
3.72
1
T2-556 AL 37 ST
330,465
1,272,737
1,603,202
156
CBEC
Indian Creek East
161
161
5.34
1
1192AL/T2-556ACSR
23,264
967,644
990,908
157
Indian Creek East
Manawa
161
161
0.29
1
1192AL/T2-556ACSR
1,548
64,393
65,941
158
Manawa
Sub 702
161
161
2.26
2
1192AL61STR,T556
10,289
332,546
342,835
159
Carroll County
Drager
161
161
5.49
1
636 ACSR 26/7
15,428
144,912
160,340
160
Drager
Grand Junction
161
161
29.65
1
636 ACSR 26/7
83,322
1,337,029
1,420,351
161
N.E. Ankeny
Alliant Tap (C17)
161
161
5.12
1
T2-556 ACSR 26/7
39,362
3,418,694
3,458,056
162
Bittersweet
Big Creek
161
161
4.68
1
T2-556 ACSR 26/7
39,362
3,627,352
3,666,714
163
N.E. Ankeny
Alliant Tap (F23)
161
161
1.22
1
T2-556 ACSR 26/7
551,472
551,472
164
CBEC
(ab)
OPPD 1206
161
161
5.87
1
1192 ACSS/954
15,620
6,695,922
6,711,542
165
Sycamore
Ankeny
161
161
7.73
1
T2-556 ACSR 26/7
685,087
2,446,443
3,131,530
166
Ankeny
Ankeny NE
161
161
6.43
1
T2-556 ACSR
716,734
2,142,096
2,858,830
167
Granger
No. Highways 141 & 44 Tap
161
161
5.65
1
T2-556 ACSR
140,078
904,874
1,044,952
168
So. Highways 141 & 44 Tap
(ac)
Granger Tap
161
161
2.26
1
T2-556 ACSR
56,109
362,456
418,565
169
No. Highways 141 & 44 Tap
Highways 141 & 44 Sub
161
161
0.03
1
T2-556 ACSR
98,925
98,925
170
Highways 141 & 44 Sub
So. Highways 141 & 44 Tap
161
161
0.03
1
T2-556 ACSR
98,926
98,926
171
Granger
(ad)
Bittersweet
161
161
7.13
1
T2-556 ACSR 26/7
176,806
1,142,134
1,318,940
172
Blackhawk
Deere Foundry
161
161
6.2
2
636 ACSR 26/7
135,501
135,501
173
Leeds
Plymouth
161
161
6.15
1
636 ACSR 26/7
99,916
627,036
726,952
174
Electrifarm
Shaulis Road
161
161
5.51
1
636 ACSR&T-2 397
70,821
1,306,287
1,377,108
175
Shaulis Road
Washburn
161
161
6.15
1
636 ACSR&T-2 397
6,049
1,466,542
1,472,591
176
Deere Engine
Electrifarm
161
161
2.74
1
636 ACSR 26/7
3,349
229,686
233,035
177
Waterloo West
Deere Engine
161
161
4.85
2
636 ACSR 26/7
5,884
531,395
537,279
178
Waterloo West
Deere Foundry
161
161
0.64
1
636 ACSR 26/7
802
338,654
339,456
179
Black Hawk - Midport
Lundquist
161
161
1.26
5.52
2
636 ACSR 26/7
9,305
487,209
496,514
180
Kellogg
Leeds
161
161
3.52
1
636 ACSR 26/7
57,187
719,670
776,857
181
Lundquist
Deere NE
161
161
4.04
0.45
2
636 ACSR 26/7
1,096,375
1,096,375
182
Deere Foundry
Deere Component
161
161
0.91
2
636 ACSR 26/7
13,322
567,164
580,486
183
Deere Component
Lundquist
161
161
0.47
1
636 ACSR 26/7
1,084
299,711
300,795
184
Deere Northeast
Washburn
161
161
7.94
1
636 ACSR 26/7
2,273,634
2,273,634
185
Raun
Interchange
161
161
9.01
2
954 ACSR 45/7
149,955
834,170
984,125
186
Interchange
Kellogg
161
161
4.62
2
954 ACSR 45/7
71,322
972,314
1,043,636
187
Sub K - Coralridge Sub
Coralridge Sub - Sub P
161
161
7.15
1
1192 ACSR 54/19
247,110
1,523,922
1,771,032
188
Sub 77
Hydrocarbon
161
161
3.98
1
1192 ACSR 54/19
62,623
701,614
764,237
189
Sub 74
Sub 77
161
161
2.98
2
1192 ACSR 54/19
46,888
543,747
590,635
190
Hydrocarbon
Sub 91
161
161
2.61
1
1192 ACSR 54/19
41,067
474,072
515,139
191
Switching Station 79
Sub 91
161
161
8.15
1
1192 ACSR 54/19
73,966
1,260,879
1,334,845
192
Sub 58 Tap
Sub 58
161
161
2.69
1
954 ACSR 45/7
19,258
424,375
443,633
193
Sub 48
Sub A
161
161
2.84
1.98
2
1192 ACSR 54/19
85,446
940,567
1,026,013
194
Ashawa
16th & Wabash
161
161
6.34
1
1192 AL 61 STR
138,774
2,715,267
2,854,041
195
SE Polk - Easter
Glover & Watrous
161
161
5.36
1
T2-556 AL 37 ST
766,125
766,125
196
Glover & Watrous
16th & Wabash
161
161
2.65
1
T2-556 AL 37 ST
775,575
775,575
197
Forest & Vermont - MLK
16th & Wabash
161
161
2.56
2
1192 AL 61 STR
125,780
1,414,709
1,540,489
198
Forest & Vermont
Sycamore
161
161
6.82
1
1192 AL 61 STR
320,014
4,200,276
4,520,290
199
Sub 39
Sub 47
161
161
2.34
1
1192 ACSR 54/19
36,457
309,989
346,446
200
Sub 47
Sub 48
161
161
2.62
1
1192 ACSR 54/19
40,819
418,700
459,519
201
Hills
Sub E
161
161
6.56
1
556 ACSR 26/7
46,963
1,931,585
1,978,548
202
Sub Y
Sub G
161
161
3.77
1
556 ACSR 26/7
26,990
569,500
596,490
203
Sub 58
Sub 76
161
161
2.68
2
954 ACSR 45/7
19,186
404,844
424,030
204
Sub E
Sub Y
161
161
1.71
1
556 ACSR 26/7
12,242
375,313
387,555
205
Sub J
Sub U
161
161
1.67
0.78
2
795 ACSR 26/7
92,454
92,454
206
Sub J
Enron Sub (IEN)
161
161
3.99
1
795 ACSR 26/7
28,564
792,468
821,032
207
Hydrocarbon (Iowa City)
Hills
161
161
3.39
1
795 ACSR 26/7
24,269
650,489
674,758
208
Northgate
Sub P
161
161
4.4
1
556 ACSR 26/7
31,428
663,158
694,586
209
Sub ICU
SUB ICP
161
161
1.16
1
795 ACSR 26/7
943,708
943,708
210
Sub ICP
3 Terminal Tie
161
161
0.05
1
T2-397 ACSR 26/7
74,923
74,923
211
Sub 70
Sub A
161
161
0.23
0.33
2
1192ACSR 45/7
4,009
52,420
56,429
212
Sub 70
Sub 88
161
161
0.04
0.76
2
795ACSR 26/7
5,727
120,849
126,576
213
Sub 71
Sub 88
161
161
4.05
1
2-397 ACSR 26/7
6,436
142,159
148,595
214
Sub 79
Sub 71
161
161
2.08
1
2-397 ACSR 26/7
4,648
111,408
116,056
215
Sub 74
Sub 79
161
161
2.08
1
2-397 ACSR 26/7
4,648
185,018
189,666
216
Sub 74
Sub 76
161
161
3.05
1.6
2
1192 ACSR 54/19
33,290
702,433
735,723
217
Sub 74
Sub 58 Tap
161
161
1.09
1
1192 ACSR 54/19
2,436
18,376
20,812
218
Sub 78
Sub 58 Tap
161
161
1.55
1
2-397 ACSR 26/7
3,464
70,883
74,347
219
Sub 56
Sub 78
161
161
6.31
1
2-397 ACSR 26/7
201,116
3,390,763
3,591,879
220
Hills
(ae)
Parnell
161
161
27.62
1
T2-397ACSR 26/7
61,588
2,022,238
2,083,826
221
Neal North
Salix Jct.
161
161
4.18
1
954 ACSR 45/7
31,021
601,768
632,789
222
LeMars South Tap
LeMars South
161
161
11.35
1
477 ACSR 26/7
1,140,333
1,140,333
223
OGS
Pleasant Corner
161
161
8.1
1
T2-556 ACSR 26/7
250,000
6,420,116
6,670,116
224
Raun
Kellogg
161
161
13.05
2
T2-556 ACSR 26/7c
1,367,524
18,489,532
19,857,056
225
Blackhawk
STR BE66
161
161
12.32
2
T2-556 ACSR 26/7
121,620
5,193,743
5,315,363
226
Adams County
Brooks
161
161
9.49
1
T2-556 ACSR 26/7
5,032,882
5,032,882
227
Enterprise Way
Sub 78
161
161
2.23
1
T2-556 ACSR 26/8
147,902
2,159,344
2,307,246
228
Less non-MEC 161kV Partial
229
ownership miles
33.86
4,216,267
841,041
536,699
5,594,007
230
161kV Expenses
231
Various locations
69
69
1,393.18
166.89
69 kV OH
4,137,805
198,913,600
203,051,405
7,210,923
1,681,524
943,698
9,836,145
36
3,816.74
346.21
267
59,267,686
1,109,056,728
1,168,324,414
12,696,183
2,685,041
1,632,310
17,013,534


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 66.82%

(b) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 66.82%

(c) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 66.82%

(d) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 66.82%

(e) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 79.10%

(f) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 79.10%

(g) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 79.10%

(h) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 79.10%

(i) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 88.70%

(j) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 86.60%

(k) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 86.60%

(l) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 79.10%

(m) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 40.57%

(n) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 40.57%

(o) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 52.00%

(p) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 72.00%

(q) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 72.00%

(r) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 72.00%

(s) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 54.73%

(t) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 62.24%

(u) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 62.24%

(v) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 62.24%

(w) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 60.78%

(x) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 50.00%

(y) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 50.00%

(z) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 52.00%

(aa) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 62.47%

(ab) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 60.77%

(ac) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 40.85%

(ad) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 40.85%

(ae) Concept: TransmissionLineEndPoint

MidAmerican Energy Company Partial Ownership - 97.28%


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Bittersweet
Big Creek
4.68
5
(e)
161
1,476,816
1,476,816
2,953,632
44
TOTAL
4.68
5
2
2
1,476,816
1,476,816
2,953,632


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: NumberOfTransmissionCircuitsPerStructurePresent

The line double circuits, with 345 and 161 circuits.

(b) Concept: NumberOfTransmissionCircuitsPerStructureUltimate

The line double circuits, with 345 and 161 circuits.

(c) Concept: ConductorSpecification

Specification:

 

ACSR 26/7

(d) Concept: ConductorConfigurationAndSpacing

12-foot spacing from shield wire to top phase, and 24-foot spacing top phase to middle phase, and 24-foot spacing from middle phase to bottom phase.

(e) Concept: OperatingVoltageOfTransmissionLine

Allocation of amounts in Columns (l), (m), & (n) is estimated.


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
16th & College, IA
Distribution
67
13.8
45
2
2
37th & Rock Island, IA
(Unattended)
67
13.8
22
1
3
38th & Franklin, IA
67
13.8
22
1
4
38th & Franklin, IA
69
13.8
25
1
5
50th & Aurora, IA
67
13.8
22
1
1
6
50th & Aurora, IA
69
13.8
25
1
7
63rd & Park, IA
67
13.8
22
1
8
73rd & Buffalo RD., IA
67
13.8
45
2
9
76th & Douglas, IA
67
13.8
45
2
10
Ackley, IA
161
13.8
13
1
11
Adel, IA
67
13.8
45
2
12
ADM, IA
69
13.8
25
1
13
Alcester, SD
69
12.47
3
1
14
Alleman, IA
67
13.8
4
1
15
Allison, IA
34.5
13.8
6
1
16
Auburn, IA
69
12.47
6
1
17
Audubon North, IA
69
12.47
20
1
18
Battle Creek, IA
69
12.47
4
1
19
Bedford, IA
34.4
13.8
13
1
1
20
Bode, IA
69
12.47
4
1
21
Boyden, IA
69
13.8
13
1
22
Brooks Substations, IA
161
13.8
22
1
23
Buck Grove, IA
67
7.2
1
24
Carroll North, IA
69
12.47
25
1
25
Charles City North, IA
69
12.47
25
1
26
Charter Oak, IA
69
13.8
6
1
27
Cherokee South, IA
69
12.47
25
1
28
Clarion, IA
69
12.47
11
1
29
Clarksville East, IA
69
13.8
6
1
30
Clarksville East, IA
69
34.5
20
1
31
Colfax, IA
69
13.8
13
1
32
Colona Road, IA
69
13.8
25
1
33
Correctionville, IA
69
13.8
6
1
34
Craig, IA
69
12.47
3
1
35
Dakota Dunes, SD
69
13.8
25
1
36
Danbury, IA
69
12.47
3
1
37
Denver, IA
69
12.47
7
1
38
Dewar, IA
69
12.47
11
1
39
Division, IA
67
12.47
50
2
40
Dow City, IA
67
12.47
5
1
41
Dumont, IA
Distribution
69
12.47
3
1
42
Dumont, IA
(Unattended)
69
34.5
14
1
43
Dunlap, IA
69
13.8
6
1
44
E 17th & Washington, IA
67
13.8
22
1
45
E 17th & Broadway, IA
67
13.2
11
1
46
E 17th & Broadway, IA
67
13.8
22
1
47
E 23rd & Dean, IA
67
13.8
45
2
48
E 29th & Hubbell, IA
67
13.8
22
1
49
E 46th & Jefferson, IA
67
13.8
16
1
50
Earling, IA
67
12.47
6
1
51
Early (Camex), IA
67
13.8
5
1
52
Early (Camex), IA
69
13.8
6
1
53
Emerson South, IA
69
13.8
6
1
54
Emmetsburg East, IA
69
13.8
13
1
55
Exira, IA
69
13.8
6
1
56
Fonda, IA
13.8
4.16
2
1
57
Gilbertville, IA
67
12.47
3
1
58
Gilmore City, IA
69
12.47
4
1
59
Glenwood, IA
67
13.8
22
1
60
Glenwood, IA
69
13.8
25
1
61
Goldfield, IA
69
13.8
13
1
62
Grand Meadow, IA
69
12.47
6
1
63
Griswold, IA
69
13.8
6
1
64
Holstein North, IA
69
13.8
13
1
65
Honey Creek, IA
69
13.8
13
1
66
Hudson, IA
13.2
4.16
1
67
Hudson, IA
13.8
4.16
2
1
68
Hull, IA
69
12.47
9
1
69
Humboldt Central, IA
67
12.47
25
1
70
Ida Grove, IA
69
12.47
25
1
71
Indianola, IA
69
13.8
13
1
72
Inwood, IA
67
12.47
4
1
73
Ireton, IA
69
12.47
6
1
74
Irwin, IA
69
12.47
6
1
75
James, IA
69
12.47
7
1
76
Janesville, IA
69
12.47
7
1
77
Jesup, IA
69
12.47
24
2
78
Kingsley, IA
69
13.8
6
1
79
Knox Gelatin, IA
67
12.47
11
1
80
Knoxville, IA
67
13.8
22
1
81
Knoxville Industrial, IA
Distribution
67
13.8
22
1
82
Lake City, IA
(Unattended)
69
13.8
13
1
83
Latimer, IA
67
12.47
4
1
84
Lawton, IA
69
13.8
6
1
85
Le Mars West, IA
69
12.47
33
1
86
Little Sioux, Council Bluffs IA
67
13.2
4
1
87
Logan, IA
67
13.8
8
1
88
Logan Park, IA
69
12.47
25
1
89
Luverne, IA
69
13.8
6
1
90
Macedonia, IA
67
13.2
11
1
91
Mahaska, IA
69
13.8
25
1
92
Malvern, IA
69
13.2
8
1
93
Mapleton, IA
69
12.47
2
3
94
Marcus East, IA
69
12.47
38
2
95
Massey Ferguson, IA
67
13.8
18
1
96
Maynard, IA
69
13.8
1
97
McCook, SD
69
12.47
50
2
98
McCoy, IA
67
12.47
7
1
99
Merrill, IA
69
12.47
3
1
100
Merrill North, IA
69
13.8
10
1
101
Midway, IA
34.4
13.8
1
3
102
Minden, IA
69
13.8
5
1
103
Mondamin, IA
67
13.2
2
1
104
Monroe, IA
67
13.2
11
1
105
Moville North, IA
69
13.8
6
1
106
Murphy, IA
69
13.8
57
3
107
Nashua, IA
69
13.8
6
1
108
New Hartford, IA
34.4
12.47
3
1
109
New Market, IA
34.4
13.8
4
1
110
New Sharon, IA
69
13.8
13
1
111
Newell Jct, IA
69
34.5
13
1
1
112
Newell Township, IA
69
13.8
10
1
113
Odebolt, IA
69
12.47
5
1
114
Orange City Rural, IA
69
13.8
6
1
115
Oskaloosa M Ave West, IA
67
13.8
22
1
116
Palmer, IA
34.5
13.8
6
1
117
Patterson, IA
67
13.2
11
1
118
Percival, IA
69
13.8
4
1
119
Plainfield, IA
69
12.47
3
1
120
Pleasant Corner, IA
161
13.8
100
2
121
Pleasantville, IA
Distribution
67
13.8
16
1
122
Pomeroy, IA
(Unattended)
34.5
13.8
6
1
123
Portsmouth, IA
67
13.2
3
3
124
Quarry Road, IA
69
13.8
13
1
125
Redfield, IA
67
13.2
13
1
126
Rock Valley, IA
69
13.8
17
1
127
Rockwell City, IA
69
12.47
20
1
128
Ruthven, IA
67
13.8
3
1
129
S.E. 124th Street, IA
67
13.8
22
1
1
130
S.E. 30th & Vandalia, IA
67
13.2
11
1
131
S.E. 30th & Vandalia, IA
69
13.8
25
1
132
Sac City, IA
69
13.8
13
1
133
Sanborn Corner, IA
69
13.8
4
1
134
Schaller, IA
69
12.47
6
1
135
Schleswig, IA
69
12.47
6
1
136
Sheffield, IA
67
13.2
11
1
137
Shell Rock, IA
69
13.2
9
1
138
Sioux City West, IA
69
12.47
25
1
139
Sioux City West, IA
69
13.2
25
1
140
Sioux River, SD
69
13.8
13
1
141
Sloan, IA
67
12.47
6
1
142
Smithland, IA
69
12.47
5
1
143
Solvay, IA
69
4.16
11
1
144
South Page, IA
67
13.2
3
1
145
SouthPark, IL
69
13.8
33
1
146
Storm Lake East, IA
69
13.8
50
2
147
Sub 101 Orion, IL
69
13.8
13
1
148
Sub 102 Stevenson, IL
67
13.8
4
1
149
Sub 104 Kain, IL
69
13.8
9
1
150
Sub 105 Crawford, IL
67
13.8
11
1
151
Sub 107 Reynolds, IL
69
13.2
5
3
152
Sub 108 Johnston, IL
69
13.2
5
3
153
Sub 111 Cederstrom, IL
67
13.8
11
1
154
Sub 20 Moline, IL
13.8
4.16
6
1
155
Sub 22 Moline, IL
69
13.8
54
2
156
Sub 25 Moline, IL
13.2
4.16
7
1
157
Sub 27 Green Rock, IL
69
13.8
14
1
158
Sub 38 Rock Island, IL
69
13.8
60
2
159
Sub 40 Moline, IL
69
13.8
53
2
160
Sub 41 Rock Island, IL
69
13.8
13
1
161
Sub 42 Rock Island, IL
Distribution
69
13.8
13
1
162
Sub 46 Silvis, IL
(Unattended)
69
13.8
13
1
163
Sub 50 Blue Grass, IA
69
13.8
13
1
1
164
Sub 53, IA
161
13.8
56
2
165
Sub 54 Camanche, IA
69
13.8
13
1
166
Sub 57 Bettendorf, IA
69
13.8
53
2
1
167
Sub 59 Davenport, IA
69
13.8
67
2
168
Sub 703, IA
67
13.8
45
2
169
Sub 704, IA
67
13.2
11
1
1
170
Sub 704, IA
67
13.8
22
1
171
Sub 705, IA
67
13.8
45
2
172
Sub 706, IA
67
13.8
45
2
173
Sub 72 Bettendorf, IA
69
13.8
71
2
174
Sub 73 Camanche, IA
69
13.8
13
1
175
Sub 75 Davenport, IA
69
13.8
53
2
176
Sub 84 LeClaire, IA
69
13.8
13
1
177
Sub B Fort Dodge, IA
69
13.8
6
1
1
178
Sub B Iowa City, IA
69
13.8
67
2
179
Sub C Moline, IL
13.2
4.16
6
1
180
Sub G Fort Dodge, IA
69
13.8
13
1
181
Sub M Fort Dodge, IA
69
13.8
6
1
182
Sub Q Fort Dodge, IA
69
13.8
60
2
183
Sub R Fort Dodge, IA
67
13.8
7
3
184
Sub U Moline, IL
13.2
4.16
6
1
185
Sub V Fort Dodge, IA
69
13.8
13
1
186
Sulphur Springs, IA
33
12.47
1
3
187
Sutherland Jct, IA
67
13.8
6
1
188
Templeton, IA
69
13.8
6
1
189
Thor, IA
67
13.2
11
1
190
Thurman, IA
67
13.2
11
1
191
Tracy, IA
69
13.8
13
1
192
Ute, IA
67
12.47
6
1
193
Walnut, IA
67
13.8
9
1
194
Waukee, IA
67
13.8
22
1
195
Westside, IA
69
12.47
6
1
196
Whiting, IA
67
12.47
6
1
197
Wida, IA
69
12.47
3
1
198
Wida, IA
69
13.8
22
1
199
Winterset Pumping ST, IA
69
4.16
4
1
200
Zeidler, IA
69
13.8
25
1
201
Beacon, IA
Transmission
161
69
13.8
334
2
202
Buena Vista, IA
(Unattended)
161
69
8.05
125
1
203
CBEC 161kV, IA
161
69
13.8
250
2
204
CBEC 69kV, IA
69
13.8
2.4
13
1
205
Floyd, IA
161
69
13.8
125
1
206
Hasting, IA
161
69
13.8
90
1
207
Hazelton, IA
345
161
13.8
336
1
208
Hills, IA
161
69
13.8
224
2
209
Hills, IA
345
161
13.8
500
1
1
210
Norwalk, IA
345
161
13.8
560
1
211
Oak Grove, IL
345
161
13.8
560
1
212
Oakland, IA
67
13.2
7
1
213
Overland Trail, IA
345
161
14
560
1
214
Plymouth, IA
161
69
13.8
150
1
215
SE Polk, IA
345
161
13.8
560
1
216
SAC County, IA
161
69
13.2
125
1
217
SUB 39, IL
161
69
13.8
125
1
218
SUB 39, IL
345
161
13.2
500
1
219
SUB 39, IL
345
161
13.8
1
220
Sub 91, IA
345
161
13.8
560
1
221
Sub K, Tiffin, IA
345
161
560
1
222
Teakwood Road, IA
161
69
13.8
90
1
223
Wall Lake, IA
161
69
13.8
83
1
224
Webster, IA
161
69
12.47
84
1
225
100th & 54th Avenue, IA
Combination T & D
161
13.8
67
2
226
100th & Douglas, IA
(Unattended)
161
13.8
66
2
227
109th & Clark, IA
161
13.8
67
2
228
142nd Street, IA
161
13.8
33
1
229
16th & Wabash, IA
161
13.8
67
2
230
16th & Wabash, IA
161
69
13.8
215
2
231
16th & Wabash, IA
67
13.8
22
1
232
16th & Wabash, IA
69
13.8
33
1
233
2nd & Broadway, IA
67
13.8
22
1
234
2nd & Broadway, IA
69
13.8
25
1
235
60th Street, IA
161
13.8
66
2
236
88th ST - WDM, IA
161
13.8
67
2
237
Airport, IA
161
13.8
67
2
238
Alices Road, IA
161
13.8
67
2
239
Altoona, IA
161
13.8
67
2
240
Ankeny, IA
161
13.8
67
2
241
Army Post Road, IA
Combination T & D
161
13.8
33
1
242
Ashawa, IA
(Unattended)
161
13.2
67
2
243
Ashawa, IA
161
69
100
1
244
Ashawa, IA
161
69
13.8
90
1
245
Avoca, IA
161
69
12.47
83
1
246
Avoca, IA
161
69
13.8
50
1
247
Avoca, IA
67
34.4
1
248
Avoca, IA
69
13.8
11
1
249
Big Creek, IA
161
13.8
33
1
250
Black Hawk, IA
161
69
13.8
50
1
251
Black Hawk, IA
345
161
13.8
560
1
252
Bondurant, IA
161
13.8
33
1
253
Booneville, IA
161
13.8
22
1
254
Booneville, IA
345
161
13.8
560
1
255
Bunge, IA
161
13.8
33
1
256
Butler, IA
161
69
34.5
33
1
257
Butler, IA
34.4
12.47
12
4
258
Butler, IA
67
34.5
22
1
259
Carroll County, IA
161
13.8
33
1
260
Carroll County, IA
161
69
13.8
173
2
261
Carroll South, IA
67
12.47
25
1
262
Charles City South, IA
69
12.47
25
1
263
Cherokee North, IA
67
12.47
25
1
264
Clarinda, IA
161
69
13.2
167
2
265
Clarinda, IA
66
34.5
13
2
1
266
Clarinda, IA
67
13.8
42
2
267
Coral Ridge, IA
161
13.8
33
1
268
Deere Northeast, IA
161
13.8
100
2
269
Delaware
161
13.8
33
1
270
DPS, IA
161
69
13.8
225
2
271
DPS, IA
67
13.8
40
2
272
Eagle Grove North, IA
69
12.47
20
1
273
Eagle Grove North, IA
69
13.8
25
1
274
Earlham, IA
161
69
13.8
90
1
275
Earlham, IA
69
13.8
13
1
276
Easter Lake, IA
161
13.8
33
1
277
Electrifarm 161, IA
161
69
13.8
100
1
278
Emmetsburg South, IA
69
13.8
20
1
279
Enterprise Way, IA
161
13.8
67
2
280
Forest & Vermont, IA
161
13.8
33
1
281
Forest & Vermont, IA
Combination T & D
161
69
13.8
179
2
282
Freedom Sub, IA
(Unattended)
69
13.8
25
1
283
Glover & Watrous, IA
161
13.8
67
2
284
Granger, IA
161
13.8
33
1
285
Greenfield Plaza, IA
161
13.8
67
2
286
Hampton West, IA
69
12.47
50
2
287
Harvest Avenue, IA
161
13.8
67
2
288
Hayes, IA
161
69
13.2
125
1
289
Hayes, IA
69
13.8
13
1
290
Hickory, IA
69
13.8
13
1
291
Hospers, IA
69
13.8
13
1
292
Humbolt East, IA
69
12.47
22
1
293
Highways 141 & 44, IA
161
13.8
33
1
294
Interchange, IA
161
12.47
67
2
295
John Deere, IA
67
13.8
45
2
296
John Deere, IA
69
13.8
33
1
297
Johnston
161
13.8
33
1
298
Kellogg, IA
161
12.47
100
3
299
Kellogg, IA
161
69
12.47
150
1
300
Leeds, IA
161
12.47
67
2
301
LeMars North, IA
69
12.47
25
1
302
Le Mars South, IA
161
69
13.8
83
1
303
Le Mars South, IA
67
12.47
50
2
304
Liberty, IA
161
13.2
100
2
305
Little Sioux, Sioux City, IA
161
69
93
1
306
Little Sioux, Sioux City, IA
67
12.47
1
2
307
Little Sioux, Sioux City, IA
69
12.47
1
1
308
Lundquist, IA
161
13.8
83
3
309
Manawa, IA
161
13.2
33
1
310
Manawa, IA
161
13.8
33
1
311
M.L. King, IA
161
13.8
67
2
312
Metro East, IA
161
13.8
33
1
313
Midport Sub, IA
161
13.8
33
1
314
Missouri Valley, IA
69
13.8
13
1
315
Monona, IA
161
69
13.8
42
1
316
Morningside, IA
161
13.2
33
1
317
Morningside, IA
161
13.8
33
1
318
NE Ankeny, IA
161
13.8
33
1
319
Neal North, IA
161
69
7.2
83
1
320
Neal South, IA
161
12.47
67
2
321
Northgate, IA
Combination T & D
161
13.8
33
1
322
Oskaloosa, IA
(Unattended)
67
13.8
38
2
323
Pomeroy 161KV, IA
161
69
34.5
50
1
324
Pomeroy 161KV, IA
69
34.5
8
1
1
325
Prairie City, IA
69
13.8
13
1
326
Quick Substation, IA
161
13.8
33
1
327
Red Oak, IA
67
13.8
45
2
328
Ridgeway, IA
69
13.2
18
1
329
Ridgeway, IA
69
13.8
22
1
330
River Bend, IA
161
13.8
33
1
331
Riverhills, IA
67
13.2
22
1
332
Riverhills, IA
67
13.8
59
2
333
Riverhills, IA
69
13.2
136
2
334
Riverhills, IA
69
13.8
67
2
335
Shaulis Road, IA
161
13.8
33
1
336
Sheldon, IA
69
13.8
50
2
337
Shenandoah, IA
67
13.8
45
2
338
Sidney, IA
69
13.8
6
1
339
Storm Lake North, IA
69
13.8
25
1
340
Sub 112, IL
161
13.8
13
1
341
Sub 17 Cordova, IL
161
69
13.8
53
1
342
Sub 18 Rock Island, IL
161
13.8
33
1
343
Sub 18 Rock Island, IL
161
69
13.8
292
2
1
344
Sub 18, IL
69
13.2
13
1
1
345
Sub 28 Joslin, IL
161
13.8
13
1
346
Sub 36, IL
69
13.8
33
1
347
Sub 37 East Moline, IL
69
13.2
53
2
348
Sub 43 Coal Valley, IL
161
13.8
22
1
349
Sub 47 Silvis, IL
161
13.8
33
1
350
Sub 48, IL
161
13.8
33
1
351
Sub 49, IL
161
13.8
83
2
352
Sub 55 Princeton, IA
69
13.8
13
1
353
Sub 56
161
13.8
1
354
Sub 56 Davenport, IA
161
69
13.8
250
2
355
Sub 56 Davenport, IA
345
161
13.2
500
1
356
Sub 58 Davenport, IA
161
13.8
67
2
357
Sub 701, IA
161
13.8
33
1
358
Sub 701, IA
161
69
13.8
90
1
359
Sub 701, IA
67
13.8
22
1
360
Sub 702, IA
161
13.8
67
2
361
Sub 71 Bettendorf, IA
Combination T & D
161
13.8
67
2
362
Sub 74 Davenport, IA
(Unattended)
161
13.8
53
2
363
Sub 76 Davenport, IA
161
13.8
67
2
364
Sub 77 Mount Joy, IA
161
13.8
33
1
365
Sub 78 Davenport, IA
161
13.8
67
2
366
Sub A Riverside, Bettendorf, IA
161
13.8
33
1
367
Sub A Riverside, Bettendorf, IA
161
69
50
1
368
Sub A Riverside, Bettendorf, IA
161
69
13.8
181
2
369
Sub A, IA
69
13.8
47
2
370
Sub E 69, IL
69
13.8
55
2
371
Sub E Iowa City, IA
161
13.8
67
2
372
Sub G, IA
39.8
13.8
25
3
373
Sub G, IA
69
13.8
60
2
2
374
Sub J Iowa City, IA
161
13.8
33
1
375
Sub J Iowa City, IA
161
69
13.2
75
1
376
Sub K Fort Dodge, IA
69
13.8
27
1
377
Sub P, IA
69
13.8
64
2
378
Sub P Coralville, IA
161
13.8
67
2
379
Sub R, IL
69
13.8
55
2
380
Sub S, IL
67
13.8
27
1
1
381
Sub S, IL
69
13.8
33
1
382
Sub T Fort Dodge, IA
161
13.8
83
3
383
Sub T Fort Dodge, IA
161
69
13.8
150
3
384
Sub Y Iowa City, IA
161
13.8
53
2
385
Sugar Creek, IA
161
13.8
150
3
386
Sycamore EC, IA
161
13.8
67
2
387
Sycamore EC, IA
161
69
13.8
317
2
1
388
Sycamore EC, IA
345
161
13.8
1060
2
389
Utica Ridge Substation, IA
161
13.8
33
1
390
Washburn, IA
161
13.8
33
1
391
Washburn, IA
161
69
13.8
50
1
392
Waterloo West, IA
161
13.8
33
1
393
Waverly Junction, IA
67
12.47
2
1
394
West Des Moines, IA
67
13.8
45
2
395
West Grand, IA
161
13.8
33
1
396
Willow Creek, IA
161
13.8
200
4
397
Wright, IA
161
69
13.2
83
1
398
399
Total
41,765.5
9,856.6
754.86
22128
515
22


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: SubstationNameAndLocation

These pages include only substation facilities operated by MEC. Transmission substations without transformers and generation owned facilities (generation step-up transformers) are not included on these pages.

(b) Concept: PrimaryVoltageLevel

In columns (c), (d), and (e), the voltage is represented in kV throughout the entire report.


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

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
Coal transportation
BNSF Railway Company
64,485,027
3
Relocation moving expenses
HomeServices Relocation, LLC
497,769
4
Intercompany administrative services
Berkshire Hathaway Energy Company
10,292,555
5
Intercompany administrative services
PacifiCorp
485,465
6
Transport commodity & reservation charges
Northern Natural Gas
48,956,923
7
Intercompany administrative services
MHC, Inc.
919,206
8
Title Services
Iowa Title Company
353,907
9
Equipment Repair
Racom Corporation
2,029,745
10
(a)
Total
128,020,597
19
20
Non-power Goods or Services Provided for Affiliated
21
Administrative Costs
Altalink
487,076
22
Administrative Costs
BHE Geothermal, LLC
2,079,713
23
Administrative Costs
Dakota Dunes Development Co
680,962
24
Administrative Costs
HomeServices Company
2,531,044
25
Administrative Costs
Kern River
1,507,858
26
Administrative Costs
MidAmerican Construction Services
2,589,533
27
Administrative Costs
Berkshire Hathaway Energy Company
12,854,411
28
Administrative Costs
MidAmerican Energy Services
3,849,376
29
Administrative Costs
Northern Natural Gas
7,435,283
30
Administrative Costs
PacifiCorp
4,474,034
31
Administrative Costs
BHE Renewables, LLC
4,119,462
32
Administrative Costs
NV Energy
920,506
33
Administrative Costs
Nevada Power Company
1,016,649
34
Administrative Costs
Northern Powergrid
839,862
35
Administrative Costs
Sierra Pacific Power
568,129
36
Administrative Costs
MHC, Inc
2,555,388
37
Administrative Costs
Walnut Ridge Wind, LLC
273,815
38
Total
48,783,100
42


Name of Respondent:

MidAmerican Energy Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

Year/Period of Report

End of:
2018
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfNonPowerGoodOrService

Amounts may include “convenience” payments made to vendors by one entity on behalf of, and charged to, other entities within the Berkshire Hathaway Energy Company group. Examples of such convenience payments include industry association dues, software license costs, property insurance, leadership conference costs, etc. Such affiliate charges reflect the ability to obtain price discounts as a result of larger purchasing power and do not constitute “services” as required by this page. However, due to the difficulty in identifying and quantifying such payments, they have not been excluded from the amounts being reported.

 

Amounts which are chargeable to or from another affiliate are assigned first by coding to the specific affiliate. These charges were based on actual labor, benefits and operational costs incurred. Amounts not directly assignable to an individual affiliate, such as work performed where multiple affiliates benefit, are assigned on the basis of allocations, as described below:

 

Allocator

Description

Labor and Assets

An equal weighting of each company's labor and assets expressed as a percentage of the whole ((labor % + assets %) ÷ 2) determines the portion assigned to each company. Labor is 12 months ended through December of the prior year. Assets are total assets at December 31 of the prior year. Eight combinations of this allocator are used for allocating services that benefit different companies within the holding company organization.

Legislative

and Regulatory

The Legislative and Regulatory allocation is used to allocate costs incurred by the holding company’s Legislative & Regulatory groups. The Legislative & Regulatory groups work on a variety of legislative and regulatory subject matter for select group of companies within the holding company organization. The Legislative and Regulatory allocation percentages are based on the Legislative & Regulatory groups’ estimation of the time and resources that are being spent on these selected companies.

Information Technology Infrastructure

Allocates costs related to shared information technology infrastructure owned by the affiliate to other benefited affiliates based on an aggregation of various measures of usage of such infrastructure including storage capacity utilized, number of servers utilized, server processing times, etc.

Employee Count

This allocator distributes costs to benefited affiliates based on employee counts at such affiliates as of the prior year-end.

Oracle Users

This allocator distributes costs of Oracle software and services based on the number of employees within each affiliate using such software and services.

Processes

This allocator distributes costs of electronic data interchange software and services based on the process count within each affiliate using such software or services.

Plant

This allocator distributes costs of managing the corporate insurance function based on assets for each affiliate.

 

(b) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

107.7, 107.8, 184, 236, 252, 253, 501, 567, 589, 881

(c) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

500, 553, 560, 580, 593, 870, 921, 925

(d) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

107, 165, 181, 186, 234, 242, 408, 421, 426.1, 426.4, 426.5, 921, 923, 930.2

(e) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

107, 500, 502, 510, 923

(f) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

107, 234, 252, 253, 843, 891

(g) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426.2, 426.5, 546, 560, 912, 920, 921, 923, 926, 930.2, 931

(h) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426, 426.1, 920, 921, 923, 924, 925, 926, 930.2, 931

(i) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426.1, 426.4, 426.5, 500, 506, 920, 921, 923, 924, 925, 926, 930.2, 931

(j) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

417, 426, 920, 921, 923, 926, 935

(k) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426.1, 426.4, 920, 921, 923, 924, 925, 926, 930.2, 931

(l) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426.1, 426.4, 426.5, 920, 921, 923, 924, 925, 926, 930.2, 931

(m) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

417, 426.1, 426.4, 426.5, 920, 921, 923, 924, 925, 926, 930.2, 931

(n) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

184, 426, 426.1, 426.4, 426.5, 920, 921, 923, 924, 925, 926, 930.2, 931, 935

(o) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

417, 426.1, 426.4, 426.5, 903, 912, 920, 921, 923, 924, 925, 926, 930.2, 931

(p) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426.1, 426.4, 426.5, 870, 920, 921, 923, 924 ,925, 926, 930.2, 931

(q) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426.1, 426.4, 916, 920, 921, 923, 924, 925, 926, 930.2, 931

(r) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426, 426,1, 426.4, 426.5, 500, 546, 560, 903, 920, 921, 923, 924, 925, 926, 930.2, 931

(s) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426.1, 426.4, 580, 916, 920, 921, 923, 924, 925, 926, 930.2, 931

(t) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426.1, 426.4, 920, 921, 924, 925, 926, 930.2, 931

(u) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426.1, 920, 921, 923, 924, 925, 926, 930.2, 931

(v) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

426.1, 426.4, 920, 921, 924, 925, 926, 930.2, 931

(w) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

124, 184, 228.3, 426.2, 920, 921, 923, 926, 930.2, 931

(x) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies

546, 870, 920, 921, 926, 931

XBRL Instance File
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