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Home My WebLink About20020422Hessing Direct.pdfBEFORE THE IDAHO PUBLIC UTILITIES COMMISSION IN THE MATTER OF THE APPLICATIONOF )IDAHO POWER COMPANY FOR AN ENERGY )CASE NO.IPC-E-02-2COSTFINANCINGORDERANDAUTHORITY)TO INSTITUTE AN ENERGY COST BOND )CHARGE.) IN THE MATTER OF THE APPLICATION OF )IDAHO POWER COMPANY FOR AUTHORITY )CASE NO.IPC-E-02-3TOIMPLEMENTAPOWERCOST)ADJUSTMENT (PCA)RATE FOR ELECTRIC )SERVICE FROM MAY 16,2002 THROUGH )MAY 15,2003.) DIRECT TESTIMONY OF KEITH HESSING IDAHO PUBLIC UTILITIES COMMISSION APRIL 22,2002 1 Q.Please state your name and business address for 2 the record. 3 A.My name is Keith D.Hessing and my business 4 address is 472 West Washington Street,Boise,Idaho. 5 Q.By whom are you employed and in what capacity? 6 A.I am employed by the Idaho Public Utilities 7 Commission as a Public Utilities Engineer. 8 Q.What is your educational and experience 9 background? 10 A.I am a Registered Professional Engineer in the 11 State of Idaho.I received a Bachelor of Science Degree 12 in Civil Engineering from the University of Idaho in 13 1974.Since then,I have worked six years with the Idaho 14 Department of Water Resources and two years with 15 Morrison-Knudsen.I have been continuously employed at 16 the Commission since August 1983. 17 As a member of the Commission Staff,my primary 18 areas of responsibility have been electric utility power 19 supply,revenue allocation and rate design.I have 20 worked with Idaho Power's (Company)Power Cost Adjustment 21 (PCA)mechanism since 1992 when the formative case was 22 filed. 23 Q.What is the purpose of your testimony in this 24 proceeding? 25 A.My testimony addresses the calculation of the IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)104/22/02 Staff l PCA forecast and true-up,alternatives for recovery of 2 this year's PCA costs,the design of rates,except 3 residential rates,and a Demand Side Management (DSM) 4 rate rider. 5 Q.Please summarize your testimony. 6 A.I determine that the Company's calculation of 7 the coming year's power supply forecast cost is done 8 according to the Commission-approved methodology.I 9 incorporate four adjustments proposed by Staff witness 10 Holm into the true-up calculation.These adjustments 11 reduce the true-up amount to be recovered from ratepayers 12 by approximately $16 million.I review four 13 alternatives,including the Company's three-year 14 securitization proposal,for spreading this year's PCA 15 costs over one or more years.I recommend a two-year 16 recovery period with no securitization.My proposal 17 reduces customer rates by an average of 9.6 percent in 18 the coming PCA year.I recommend that PCA rate 19 reductions be incorporated in all customer rates on an 20 equal cents per kilowatt-hour basis except residential 21 customer rates.Staff witness Schunke addresses the rate 22 design for the residential class.I propose that a 23 Demand Side Management (DSM)rate be added to all 24 customer rates to fund additional DSM program costs. 25 Q.How do you view the two cases filed by Idaho IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)204/22/02 Staff 1 Power that the Commission is reviewing in this 2 proceeding? 3 A.I view the consolidated case as Idaho Power 4 Company's 2002 Power Cost Adjustment (PCA)rate filing. I 5 The filing proposes a mechanism to recover PCA costs by 6 adjusting customer rates.The Company's proposal seeks 7 to recover PCA costs using a combination of a PCA rate 8 and a securitized rate. 9 PCA DESCRIPTION AND HISTORY 10 Q.Please describe in general Idaho Power 11 Company's Power Cost Adjustment Mechanism. 12 A.Idaho Power's PCA is a rate adjustment I 13 mechanism that annually increases or decreases customer I14ratestoreimbursetheCompanyforabovenormalorbelow 15 normal costs of supplying power.Traditional power 16 supply costs are fuel costs and purchased power costs 17 offset by sales revenues from the sale of surplus energy. 18 The two major factors that affect power supply costs are 19 Snake River drainage water supply conditions and 20 Northwest wholesale power market prices.Good water 21 conditions decrease Idaho Power's power supply costs and 22 return money to customers through reduced rates.Poor 23 water conditions increase power supply costs,which are 24 recovered from customers through increased rates. 25 Q.Traditionally,what have been the major IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)304/22/02 Staff 1 components of the PCA? 2 A.Each year's PCA has traditionally been composed 3 of a forecast or projection of costs for the coming year, 4 a true-up to actual costs of the previous year's forecast 5 and a calculation of the PCA rate.Each year's 6 forecasted PCA costs rely on the National Weather 7 Service's River Basin forecast Center April 1 forecast of 8 April through July Brownlee Reservoir inflow volumes. 9 The estimated inflow volume is used in a mathematical 10 formula that relates inflow to Idaho Power's power supply 11 costs.Only 90 percent of the above or below normal 12 forecasted power supply costs are allowed to be recovered 13 from customers in the PCA. 14 Each year the previous year's forecasted power 15 supply costs are trued-up to actual power supply costs. 16 Ninety percent of the difference from normal goes into 17 the PCA.The other 10 percent of these costs are 18 absorbed by Idaho Power Company's shareholders. 19 Finally,the PCA rate is calculated.The 20 dollar amount of the combined forecast and true-up is 21 divided by the number of kilowatt-hours (kWh)the Company 22 sells in a year.Customer rates are adjusted by this 23 ¢/kWh amount,which may either increase or decrease 24 customer rates.Staff Exhibit No.102 shows the history 25 of all PCA rate adjustments since the first PCA rate IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)404/22/02 Staff 1 adjustment was instituted in 1992.The 2002 PCA amount 2 of $253.8 million is the amount I calculate,including 3 Staff adjustments,for the 2002 PCA year.In all PCA 4 years through 2001,the PCA amount has been recovered 5 from or credited to ratepayers in a single year.Some of 6 the options in this case would spread the recovery over 7 two or more years. 8 I THE PCA FORECAST 9 Q.What is the Company's proposed PCA forecast? 10 A.The Company proposes that the PCA forecast rate 11 be .2156 ¢/kWh.The rate is based on Brownlee inflows of 12 3.63 million acre-feet in the April through July period 13 this year.The Brownlee inflow forecast of 3.63 million 14 acre-feet is only 58 percent of normal.Last winter's 15 precipitation was well above 58 percent of normal. 16 However,there are several large reservoirs above 17 Brownlee Reservoir on the Snake River.Due to last 18 year's drought,these upstream reservoirs are low and 19 will require more of the available water than normal in 20 the April through July period.Therefore,the forecast 21 predicts only 58 percent of normal Brownlee inflow during 22 the April through July period. 23 Q.Do you agree with the Company's calculation of 24 the forecast rate? 25 A.Yes I do.I have checked the April through IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)504/22/02 Staff 1 July Brownlee inflow estimate and verified that the 2 Commission-approved methodology has been correctly 3 applied.Staff Exhibit No.103 graphically represents 4 the computation of forecast PCA expense,which is later 5 used to calculate the forecast portion of the PCA rate. 6 I expect the proposed forecast rate to recover 7 approximately $27.5 million dollars during the PCA year. 8 THE PCA TRUE-UP 9 Q.What does the Company calculate the true-up for 10 2001-2002 to be? 11 A.The Company's true-up calculation to last 12 year's forecast,after jurisdictional allocation and 13 sharing between ratepayers and shareholders,indicates 14 that Idaho ratepayers are responsible for approximately 15 $223 million in unrecovered power supply costs and 16 I miscellaneous items accorded PCA treatment.(Company 17 Exhibit No.3)The true-up calculations contain 18 irrigation and Astaris load reduction costs,which 19 replaced market purchases,and some other new items 20 approved by the Commission for PCA treatment.Staff 21 witness Holm further discusses some of the components in 22 the true-up calculation. 23 Q.Does the Staff agree with the Company's true-up 24 calculation? 25 A.Staff witness Holm proposes four changes to the IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)604/22/02 Staff 1 Company's true-up calculation.He proposes that lost 2 revenue be removed from irrigation load reduction program 3 costs,that an adjustment be made to mobile generation 4 costs and that two adjustments be made to the operating 5 costs of Idaho Power's Mountain Home Combustion Turbine. 6 These adjustments to the Company's true-up calculation 7 are shown on Staff Exhibit No.104,pages 1 and 2.Page 8 1 shows March through October 2001 and page 2 shows 9 November 2001 through March 2002.The Staff adjustments 10 are in bold and shown on lines 14,17 and 21.They are 11 all reductions to the Company's actual PCA expense. 12 Q.What is the amount of the true-up recommended 13 by Staff? 14 A.The Staff adjustments to the true-up 15 calculation previously discussed reduce the amount of the 16 true-up from $223 million proposed by the Company to 17 approximately $207 million. 18 PCA COST RECOVERY OTIONS 19 Q.How does Idaho Power propose to recover this 20 year's PCA cost? 21 A.Idaho Power proposes that part of the cost of 22 last year's true-up and the unrecovered portion of last 23 year's October PCA rate adjustment be spread over three 24 years.Idaho Power proposes to sell bonds and adjust 25 customer rates each year to ensure that the bonds are IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)704/22/02 Staff 1 retired in three years.This bonding process is called 2 securitization.The securitized rates would also recover 3 bond interest and the cost of bonding.The remaining 4 unsecuritized portion of the true-up and the forecast 5 would be recovered using a normal PCA rate adjustment 6 over a one-year period. 7 Under the Company's proposal,this year's PCA 8 rates would have a PCA component and a securitization 9 component.The Company's proposal offers customers an 10 average 6.6 percent decrease from existing rates in the 11 coming PCA year. 12 The Company proposes to securitize $172 13 million.This amount is composed of $147 million in 14 true-up costs,$18 million in unrecovered October 2001 15 PCA costs and $7 million in bonding costs.Bond interest 16 is in addition to the $172 million.As previously 17 mentioned,the securitization rate paid by customers also 18 includes bond interest,which can be estimated but is not 19 known until the bonds are sold.The one-year PCA rate is 20 composed of the remaining true-up amount of approximately 21 $76 million and the forecast amount of $28.5 million. 22 Under the Company's proposal,PCA rates would 23 also decrease at the beginning of the second and third 24 PCA years,returning to base levels at the beginning of 25 the fourth year.Securitization causes additional IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)804/22/02 Staff 1 interest and bonding costs. 2 Q.Have you reviewed additional options for the 3 recovery of this year's PCA costs? 4 A.Yes.I have examined four options.Option No. 5 I 1 is the Company's securitization proposal with Staff's 6 adjusted true-up.None of the other three options 7 include securitization.Option No.2 recovers all of the 8 PCA costs in the first PCA year,which requires an 9 increase above existing rates.Option No.3 continues 10 the existing rates in the first PCA year and carries the 11 unrecovered costs over to the 2003 PCA year with 12 interest.Option No.4 reduces rates in the first year 13 by an average amount of 9.6 percent,7.8%for Residential 14 customers,and carries the unrecovered amount into the 15 2003 PCA year for recovery.The four options are 16 compared in Staff Exhibit No.105. 17 Q.Please describe Staff Exhibit No.105. 18 A.Staff Exhibit No.105 identifies each of the 19 four options across the top of the columns.The cost 20 recovery proposed for each option is broken down by year 21 in the top three sections on the page.Each year 22 identifies costs to be recovered in that year under the 23 traditional "PCA"mechanism and with "Securitization". 24 The bottom section on the page totals the recovery over 25 the three years identified.The bottom line on the page IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)904/22/02 Staff 1 demonstrates that the total costs are the same for all 2 four options excluding interest and bonding. 3 Option 2,one year recovery,is the lowest cost 4 option because it has no additional interest or bonding 5 costs.Option 3,existing rates continued,demonstrates 6 the next lowest total cost.It includes $1.8 million in 7 interest costs associated with carrying $26.1 million 8 into the second PCA year for recovery.The third-lowest 9 cost option is Option 4.Due to the substantial first 10 year rate decrease it offers,it carries $96.6 million 11 into the second year which accumulates $6.8 million in 12 interest.Option 1,the securitization proposal is the 13 most expensive option.Over three years it incurs $11.9 14 million in interest costs and $9.4 million in bonding 15 costs. 16 In Option 1,bond interest has been assumed at 17 4 percent.In Options 2,3 and 4,interest has been 18 assumed at 7 percent on the amount that is carried over 19 from one year to the next.Staff witness Holm makes the 20 Staff's proposal concerning appropriate interest rates 21 for PCA purposes.That proposal has not been included 22 here due to the compressed time allowed for processing of 23 this case.Interest differences are small and would not 24 affect Staff's proposal in this case. 25 Q.Which option do you recommend to the IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)1004/22/02 Staff l Commission? 2 A.I recommend option 4,which immediately 3 decreases rates and avoids bonding costs and some of the 4 interest costs associated with securitization.It also 5 recovers this year's PCA costs in two years,which 6 reduces the probability that a PCA true-up or forecast in 7 the third year would push rates to higher levels than 8 that year's PCA alone would require.This type of 9 exposure exists during the second year of each option 10 except Option 2 which recovers all of this year's PCA 11 costs in the first year but requires an increase over 12 existing rates to do it. 13 Q.Have you prepared exhibits that show the impact 14 of each of the options that you previously discussed on 15 each of the Company's customer classes? 16 A.Yes I have.Staff Exhibit No.106,pages 1 17 through 4 shows the expected impact of the Company's 18 proposal,modified to reflect the Staff's true-up 19 adjustments,on customer rates over the next 4 PCA years. 20 Staff Exhibit No.107,pages 1 and 2,shows the rate 21 impact of Staff Option 2,single year recovery.Staff 22 Exhibit No.108,pages 1 through 3,shows the rate impact 23 of Option 3,current rates continued.Staff Exhibit No. 24 109,pages 1 through 3,shows the rate impact of Staff 25 Option 4,which provides for an average 9.6 percent first IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)1104/22/02 Staff 1 year decrease without securitization. 2 The above analysis is limited to the effects 3 resulting from the decisions that the Commission will 4 make this year.Any future variations from normal water 5 conditions or normal power supply costs may cause other 6 rate differences in PCA years after 2002 that are not 7 contemplated in this testimony. 8 Q.How have you treated the $18 million in 9 unrecovered 2001 PCA costs that are scheduled for 10 recovery between May 16,2002 and September 30,2002? 11 A.I respread the costs over full PCA years in 12 each of the options that I have presented.The drawback 13 of respreading the $18 million to recover these costs is 14 that summer energy users receive lower rates that are 15 paid by winter energy users.It is a trade-off that 16 eliminates multiple PCA rate changes in the same year. 17 Also $18 million is a relatively small amount of the $253 18 million that I am proposing for recovery. 19 CUSTMER CLASS RATE DESIGN 20 Q.How does the Company propose to adjust rates 21 within customer classes to recover PCA costs? 22 A.Idaho Power proposes that the energy rate 23 within each customer class be adjusted by an equal 24 cents/kWh amount (i.e.,a flat rate)to recover the 25 approved revenue.Schedules without energy-based rate IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)1204/22/02 Staff 1 components,such as lighting schedules,should have rates 2 adjusted by an equal percentage amount that recovers the 3 required revenue. 4 Q.Do you agree with the Company's proposal? 5 A.Yes,except for residential class rates.Staff 6 witness Schunke addresses the design of Residential rates 7 in his testimony. 8 Q.Did the Commission order a portion of the costs 9 included in this year's PCA true-up calculation be 10 recovered from a specific class of customer? 11 A.Yes.Orders in two different cases required 12 that intervenor funding awarded to the irrigation class 13 be included in the PCA and be recovered from irrigators. 14 This would require that the PCA rate for irrigators be 15 different than the PCA rate for all other customer 16 classes.Given the very small amount subject to recovery 17 and the fact that the PCA is not set up to apply 18 different rates to different customer classes,Staff 19 suggests that the $20,134 in question be spread to all 20 customer classes.Apparently the Company also proposes 21 to do this since it is included in the "Intervenor 22 Funding"line on Company Exhibit No.3 that is spread to 23 all customer classes. 24 Q.Are the rates shown in Column 9 of Staff 25 Exhibit Nos.106,107,108 and 109 the energy rates that IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)1304/22/02 Staff l would result from the four proposals that you have 2 reviewed? 3 A.No.The rates shown in Column 9 of the 4 referenced Staff exhibits are average rates that are 5 calculated using all revenues normally received from the 6 class.The actual energy rate for each customer class, 7 which is the base energy rate plus any PCA adjustments, 8 is shown as the "effective rate"on each of the Company's 9 rate schedules. 10 DSM RATE RIDER 11 Q.Given that electricity wholesale market prices 12 have returned to more normal ranges since the price spikes 13 that occurred in 2000 and 2001,what is Staff's position 14 regarding Idaho Power's proposal filed July 31,2001 in 15 Case No.IPC-E-01-13 to implement additional conservation 16 efforts that would be funded through a 0.5%energy 17 surcharge? 18 A.The Staff position essentially remains the same 19 as when it filed its comments on September 20,2001. 20 Although many of the conditions that caused the wholesale 21 electricity price spikes have now abated,some 22 conservation and other demand side management (DSM) 23 measures may be economically viable resources for meeting 24 customer demand.In addition,having a DSM funding 25 mechanism and programs in place allows a quicker ramp-up IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)1404/22/02 Staff 1 of DSM efforts in the event that wholesale electricity 2 prices increase dramatically in the future. 3 Q.In that case the Staff supported Idaho Power's 4 proposed energy surcharge based on 0.5%of the Company's 5 base revenue requirement.It was estimated that the 6 surcharge would provide approximately $2.6 million 7 annually for DSM measures.Does the Staff still support 8 this amount of DSM funding? 9 A.Yes. 10 Q.What DSM rate would result from 0.5%of base 11 revenue spread over normalized energy in this case? 12 A.The DSM rate rider would be 0.0192 ¢/kWh.The 13 actual calculation is: 14 (.005)(508,321,215)/(13,209,552)=0.192 $/MWh =0.0192 15 ¢/kWh. I16i Q.Do you propose to include the DSM rate rider in 17 i rates as part of this filing? 18 A.Yes.Due to the extremely compressed 19 processing time associated with this case,the DSM rider 20 is not shown in the calculation of rates anywhere in this 21 filing. 22 Q.How do you propose the DSM rate rider be 23 incorporated into the Company's rates? 24 A.The DSM rate rider can either be added to the 25 first year rates calculated in this case,causing smaller IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)1504/22/02 Staff 1 decreases or larger increases,or the tariff rider can be 2 added with an equivalent amount of true-up costs being 3 deferred to the following year.The latter would not 4 affect first year increases or decreases but would affect 5 rates throughout the remainder of the recovery period by 6 a relatively small amount. 7 With regard to Staff's proposal in this case,I 8 recommend that $2,541,606 of additional PCA true-up costs 9 be deferred to the 2003 PCA year with interest.So doing 10 allows the customers to receive the full decrease 11 proposed by Staff for this PCA year. 12 Q.Does this conclude your direct testimony in 13 this proceeding? 14 A.Yes,it does. 15 16 17 18 19 20 21 22 23 24 25 IPC-E-02-2/IPC-E-02-3 HESSING,K (Di)1604/22/02 Staff CERTIFICATE OF SERVICE I HEREFY CERTIFY THAT I HAVE THIS 22ND DAY OF APRIL 2002,SERVED THE FOREGOING DIRECT TESTIMONY OF KEITH HESSING,IN CASENOS.IPC-E-02-02/IPC-E-02-03,BY MAILING A COPY THEREOF,POSTAGEPREPAID,TO THE FOLLOWING: LARRY D RIPLEY JOHN R GALE VICE PRESIDENTSENIORATTORNEYREGULATORYAFFAIRSIDAHOPOWERCOMPANYIDAHOPOWERCOMPANYPOBOX70POBOX70BOISEID83707-0070 BOISE ID 83707-0070 PETER J RICHARDSON WILLIAM M EDDIERICHARDSON&O'LEARY PPLC LAND &WATER FUND OF THE ROCKIESPOBOX1849POBOX1612EAGLEID83616BOISEID83701 R SCOTT PASLEY DAVID H HAWK,DIRECTORASSISTANTGENERALCOUNSELENERGYNATURALRESOURCESJRSIMPLOTCOMPANYJRSIMPLOTCOMPANYPOBOX27POBOX27BOISEID83707-0027 BOISE ID 83707-0027 SECRETARY CERTIFICATEOF SERVICE Co m m i s s i o n St a f f Pr o p o s a l - Op t i o n No . 4 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 10 / 1 / 0 1 PC A Ra t e s to 5/ 1 6 / 0 2 PC A Ra t e s Fir s t Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Li n e Sc h . 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Cu s t o m e r s (k W h ) Re v e n u e Ad j u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s Re v e n u e ¢/ k W h Ch a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 28 6 , 1 4 2 , 7 5 5 (2 2 , 2 2 3 , 8 8 7 ) 0 0 26 3 , 9 1 8 , 8 6 8 6. 3 4 3 -7 . 7 7 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 21 , 7 3 8 , 8 7 5 (1 , 4 4 7 , 5 9 6 ) 0 0 20 , 2 9 1 , 2 7 9 7. 4 8 7 -6 . 6 6 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 15 0 , 7 3 8 , 7 1 6 (1 5 , 2 4 3 , 9 2 2 ) 0 0 13 5 , 4 9 4 , 7 9 4 4. 7 4 7 -1 0 . 1 1 % 4 Du s k to Da w n Li g h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 5 1 7 , 1 7 2 (3 2 , 1 0 9 ) 0 0 1, 4 8 5 , 0 6 3 24 . 7 0 2 -2 . 1 2 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 87 , 5 5 4 , 2 8 1 (1 0 , 3 7 8 , 2 5 6 ) 0 0 77 , 1 7 6 , 0 2 5 3. 9 7 2 -1 1 . 8 5 % 6 tr r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 10 0 , 4 4 7 , 8 3 8 (9 , 8 0 5 , 7 6 3 ) 0 0 90 , 6 4 2 , 0 7 5 4. 9 3 7 -9 . 7 6 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 , 3 1 0 , 7 1 6 91 8 , 6 7 8 (7 6 , 4 3 4 ) 0 0 84 2 , 2 4 4 5. 8 8 5 -8 . 3 2 % 8 Mu n i c i p a l St r e e t Lig h t i n g 41 84 16 , 2 8 8 , 1 8 4 2, 1 2 1 , 3 3 0 (8 6 , 9 9 5 ) 0 0 2, 0 3 4 , 3 3 5 12 . 4 9 0 -4 . 1 0 % 9 Tr a f f i c Co n t r o l Li g h t i n g 42 56 11 , 9 4 4 , 0 4 2 37 0 , 9 5 8 (6 3 , 7 9 3 ) O 0 30 7 , 1 6 5 -1 7 . 2 0 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 65 1 , 5 5 0 , 6 0 3 (5 9 , 3 5 8 , 7 5 5 ) 0 0 59 2 , 1 9 1 , 8 4 8 5. 3 2 8 -9 . 1 1 % Sp e c i a l Co n t r a c t s : 11 Mi c r o n 26 1 56 6 , 1 5 4 , 0 1 2 23 , 6 2 3 , 7 4 4 (3 , 0 2 3 , 8 2 9 ) 0 0 20 , 5 9 9 , 9 1 5 3. 6 3 9 -1 2 . 8 0 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 41 , 4 4 0 , 4 6 9 (5 , 6 2 9 , 8 4 1 ) 0 0 35 , 8 1 0 , 6 2 8 3. 3 9 7 -1 3 . 5 9 % 13 JR Si m p l o t 29 1 27 3 , 3 8 3 , 7 9 5 11 , 4 3 6 , 9 2 2 (1 , 4 6 0 , 1 4 3 ) 0 0 9, 9 7 6 , 7 7 9 3. 6 4 9 -1 2 . 7 7 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 8, 0 1 5 , 3 6 7 (1 , 0 7 9 , 6 5 0 ) 0 0 6, 9 3 5 , 7 1 7 m -1 3 . 4 7 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 84 , 5 1 6 , 5 0 2 (1 1 , 1 9 3 , 4 6 3 ) 0 0 73 , 3 2 3 , 0 3 9 3. 4 9 9 -1 3 . 2 4 % 16 To t a l An n u a l Id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 73 6 , 0 6 7 , 1 0 5 (7 0 , 5 5 2 , 2 1 8 ) 0 0 66 5 , 5 1 4 , 8 8 7 5. 0 3 8 -9 . 5 9 % 17 5/ 1 6 / 0 2 PC A Ra t e (p r o p o s e d ) 1. 1 9 0 0 ce n t s / k W h 18 10 / 1 / 0 1 PC A Ra t e (e x p i r i n g ) 1. 7 2 4 1 ce n t s / k W h 19 Se c u r i t i z a t i o n 0. 0 0 0 0 ce n t s / k W h Co m m i s s i o n St a f f Pr o p o s a l - Op t i o n No . 4 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 5/ 1 6 / 0 2 PC A Ra t e s to 5/ 1 6 / 0 3 PC A Ra t e s Se c o n d Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s Pr o p o s e d PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Li n e Sc h . Nu m b e r of No r m a l i z e d 5/ 1 6 / 2 0 0 2 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 3 Av e r a g e Pe r c e n t No . Ta r i f f De s c r i p t i o n No . Cu s t o m e r s (k W h ) Re v e n u e Ad j u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s Re v e n u e g/ k W h Ch a n g e Un i f o r r n Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 26 3 , 9 1 8 , 8 6 8 (1 6 , 9 5 1 , 9 0 3 ) 0 0 24 6 , 9 6 6 , 9 6 5 5. 9 3 5 -6 . 4 2 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 20 , 2 9 1 , 2 7 9 (1 , 1 0 4 , 1 9 5 ) 0 0 19 , 1 8 7 , 0 8 4 7. 0 7 9 -5 . 4 4 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 13 5 , 4 9 4 , 7 9 4 (1 1 , 6 2 7 , 7 3 6 ) 0 0 12 3 , 8 6 7 , 0 5 7 4. 3 4 0 -8 . 5 8 % 4 Du s k to Da w n Lig h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 4 8 5 , 0 6 3 (2 4 , 4 9 2 ) 0 0 1, 4 6 0 , 5 7 0 24 . 2 9 5 -1 . 6 5 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 77 , 1 7 6 , 0 2 5 (7 , 9 1 6 , 3 1 0 ) 0 0 69 , 2 5 9 , 7 1 5 3. 5 6 4 -1 0 . 2 6 % 6 fr r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 90 , 6 4 2 , 0 7 5 (7 , 4 7 9 , 6 2 5 ) 0 0 83 , 1 6 2 , 4 4 9 4. 5 3 0 -8 . 2 5 % 7 Un r n e t e r e d Ge n e r a l Se r / i c e 40 80 6 14 , 3 1 0 , 7 1 6 84 2 , 2 4 4 (5 8 , 3 0 2 ) 0 0 78 3 , 9 4 3 5. 4 7 8 -6 . 9 2 % 8 Mu n i c i p a l St r e e t Li g h t i n g 41 84 16 , 2 8 8 , 1 8 4 2, 0 3 4 , 3 3 5 (6 6 , 3 5 8 ) 0 0 1, 9 6 7 , 9 7 7 12 . 0 8 2 -3 . 2 6 % 9 Tr a f f i c Co n t r o l Li g h t i n g 42 56 11 , 9 4 4 , 0 4 2 30 7 , 1 6 5 (4 8 , 6 6 0 ) 0 0 25 8 , 5 0 5 2B -1 5 . 8 4 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 59 2 , 1 9 1 , 8 4 8 (4 5 , 2 7 7 , 5 8 3 ) 0 0 54 6 , 9 1 4 , 2 6 5 4. 9 2 1 -7 . 6 5 % Sp e c i a l Co n t r a c t s : 11 Mi c r o n 26 1 56 6 , 1 5 4 , 0 1 2 20 , 5 9 9 , 9 1 5 (2 , 3 0 6 , 5 1 1 ) 0 0 18 , 2 9 3 , 4 0 4 3. 2 3 1 -1 1 . 2 0 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 35 , 8 1 0 , 6 2 8 (4 , 2 9 4 , 3 2 2 ) 0 0 31 , 5 1 6 , 3 0 6 2. 9 9 0 -1 1 . 9 9 % 13 JR Si m p l o t 29 1 27 3 , 3 8 3 , 7 9 5 9, 9 7 6 , 7 7 9 (1 , 1 1 3 , 7 6 6 ) 0 0 8, 8 6 3 , 0 1 4 3. 2 4 2 -1 1 . 1 6 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 6, 9 3 5 , 7 1 7 (8 2 3 53 4 ) 0 0 6, 1 1 2 , 1 8 2 39 2 4 -1 1 . 8 7 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 73 , 3 2 3 , 0 3 9 (8 , 5 3 8 , 1 3 3 ) 0 0 64 , 7 8 4 , 9 0 6 3. 0 9 1 -1 1 . 6 4 % 16 To t a l An n u a l Id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 66 5 , 5 1 4 , 8 8 7 (5 3 , 8 1 5 , 7 1 6 ) 0 0 61 1 , 6 9 9 , 1 7 1 4. 6 3 1 -8 . 0 9 % ( N M 17 5/ 1 6 / 0 3 PC A Ra t e (p r o p o s e d ) 0. 7 8 2 6 ce n t s / k W h 18 5/ 1 6 / 0 2 PC A Ra t e (e x p i r i n g ) 1. 1 9 0 0 ce n t s / k W h 19 Se c u r i t i z a t i o n 0. 0 0 0 0 ce n t s / k W h Co m m i s s i o n St a f f Pr o p o s a l - Op t i o n No . 4 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 5/ 1 6 / 0 3 PC A Ra t e s to 5/ 1 6 / 0 4 PC A Ra t e s Th i r d Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) 19 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s Pr o p o s e d PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Li n e Sc h . Nu m b e r of No r m a l i z e d 5/ 1 6 / 2 0 0 3 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 4 Av e r a g e Pe r c e n t No . Ta r i f f De s c r i p t i o n No . Cu s t o m e r s (k W Re v e n u e Ad j u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s å ¢/ k W h Ch a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 24 6 , 9 6 6 , 9 6 5 (3 2 , 5 6 3 , 9 6 5 ) 0 0 21 4 , 4 0 3 , 0 0 0 5. 1 5 3 -1 3 . 1 9 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 19 , 1 8 7 , 0 8 4 (2 , 1 2 1 , 1 1 7 ) 0 0 17 , 0 6 5 , 9 6 7 6. 2 9 7 -1 1 . 0 5 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 12 3 , 8 6 7 , 0 5 7 (2 2 , 3 3 6 , 4 4 2 ) 0 0 10 1 , 5 3 0 , 6 1 6 3. 5 5 7 -1 8 . 0 3 % 4 Du s k to Da w n Li g h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 4 6 0 , 5 7 0 (4 7 , 0 4 9 ) 0 0 1, 4 1 3 , 5 2 1 23 . 5 1 2 -3 . 2 2 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 69 , 2 5 9 , 7 1 5 (1 5 , 2 0 6 , 9 3 3 ) 0 0 54 , 0 5 2 , 7 8 1 2. 7 8 2 -2 1 . 9 6 % 6 Ir r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 83 , 1 6 2 , 4 4 9 (1 4 , 3 6 8 , 0 7 8 ) 0 0 68 , 7 9 4 , 3 7 1 3. 7 4 7 -1 7 . 2 8 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 , 3 1 0 , 7 1 6 78 3 , 9 4 3 (1 1 1 , 9 9 6 ) 0 0 67 1 , 9 4 7 4. 6 9 5 -1 4 . 2 9 % 8 Mu n i c i p a l St r e e t Lig h t i n g 41 84 16 , 2 8 8 , 1 8 4 1, 9 6 7 , 9 7 7 (1 2 7 , 4 7 1 ) 0 0 1, 8 4 0 , 5 0 5 11 . 3 0 0 -6 . 4 8 % 9 Tr a f f i c Co n t r o l Li g h t i n g 42 5_ 6 11 , 9 4 4 , 0 4 2 25 8 , 5 0 5 (9 3 . 4 7 4 ) 0 0 16 5 , 0 3 1 1. 3 8 2 -3 6 . 1 6 % 10 Su b - T o t a \ 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 54 6 , 9 1 4 , 2 6 5 (8 6 , 9 7 6 , 5 2 5 ) 0 0 45 9 , 9 3 7 , 7 4 0 4. 1 3 8 -1 5 . 9 0 % Sp e c i a l Co n t r a c t s : 11 Mic r o n 26 1 56 6 , 1 5 4 , 0 1 2 18 , 2 9 3 , 4 0 4 (4 , 4 3 0 , 7 2 1 ) 0 0 13 , 8 6 2 , 6 8 3 2. 4 4 9 -2 4 . 2 2 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 31 , 5 1 6 , 3 0 6 (8 , 2 4 9 , 2 3 0 ) 0 0 23 , 2 6 7 , 0 7 6 2. 2 0 7 -2 6 . 1 7 % 13 JR Si m p l o t 29 1 27 3 , 3 8 3 , 7 9 5 8, 8 6 3 , 0 1 4 (2 , 1 3 9 , 5 0 2 ) 0 0 6, 7 2 3 , 5 1 2 2. 4 5 9 -2 4 . 1 4 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 6, 1 1 2 , 1 8 2 (1 . 5 8 1 97 8 ) 0 0 4, 5 3 0 , 2 0 5 21 -2 5 . 8 8 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 64 , 7 8 4 , 9 0 6 (1 6 , 4 0 1 , 4 3 1 ) 0 0 48 , 3 8 3 , 4 7 5 2. 3 0 9 -2 5 . 3 2 % 16 To t a l An n u a l Id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 61 1 , 6 9 9 , 1 7 1 (1 0 3 , 3 7 7 , 9 5 6 ) 0 0 50 8 , 3 2 1 , 2 1 5 3. 8 4 8 -1 6 . 9 0 % 17 5/ 1 6 / 0 4 PC A Ra t e (p r o p o s e d ) 0. 0 0 0 0 ce n t s / k W h 18 5/ 1 6 / 0 3 PC A Ra t e (e x p i r i n g ) 0. 7 8 2 6 ce n t s / k W h 19 Se c u r i t i z a t i o n 0. 0 0 0 0 ce n t s / k W h Co m m i s s i o n St a f f - Op t i o n No . 3 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 10 / 1 / 0 1 PC A Ra t e s to 5/ 1 6 / 0 2 PC A Ra t e s Fi r s t Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Li n e Sc h . Nu m b e r of No r m a l i z e d 10 / 1 / 2 0 0 1 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 2 Av e r a g e Pe r c e n t No . Ta r i f f De s c r i p t i o n No . Cu s t o m e r s (k W h } Re v e n u e Ad j u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s Re v e n u e g/ R Ch a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 28 6 , 1 4 2 , 7 5 5 0 0 0 28 6 , 1 4 2 , 7 5 5 6. 8 7 7 0. 0 0 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 21 , 7 3 8 , 8 7 5 0 0 0 21 , 7 3 8 , 8 7 5 8. 0 2 1 0. 0 0 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 15 0 , 7 3 8 , 7 1 6 0 0 0 15 0 , 7 3 8 , 7 1 6 5. 2 8 1 0. 0 0 % 4 Du s k to Da w n Li g h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 5 1 7 , 1 7 2 0 0 0 1, 5 1 7 , 1 7 2 25 . 2 3 6 0. 0 0 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 87 , 5 5 4 , 2 8 1 0 0 0 87 , 5 5 4 , 2 8 1 4. 5 0 6 0. 0 0 % 6 Ir r i g a t i o n Se r v i c e 24 12 , 3 4 3 1,8 3 5 , 9 4 1 , 4 5 4 10 0 , 4 4 7 , 8 3 8 0 0 0 10 0 , 4 4 7 , 8 3 8 5. 4 7 1 0. 0 0 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 , 3 1 0 , 7 1 6 91 8 , 6 7 8 0 0 0 91 8 , 6 7 8 6. 4 2 0 0. 0 0 % 8 Mu n i c i p a l St r e e t Li g h t i n g 41 84 16 , 2 8 8 , 1 8 4 2, 1 2 1 , 3 3 0 0 0 0 2, 1 2 1 , 3 3 0 13 . 0 2 4 0. 0 0 % 9 Tr a f f i c Co n t r o i Lig h t i n g 42 _5 6 11 , 9 4 4 , 0 4 2 37 0 , 9 5 8 0 0 0 37 0 , 9 5 8 _3 2 1 _ 0 6 0. 0 0 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 65 1 , 5 5 0 , 6 0 3 0 0 0 65 1 , 5 5 0 , 6 0 3 5. 8 6 3 0. 0 0 % Sp e c i a l Co n t r a c t s : 11 Mic r o n 26 1 56 6 , 1 5 4 , 0 1 2 23 , 6 2 3 , 7 4 4 0 0 0 23 , 6 2 3 , 7 4 4 4. 1 7 3 0. 0 0 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 41 , 4 4 0 , 4 6 9 0 0 0 41 , 4 4 0 , 4 6 9 3. 9 3 1 0. 0 0 % 13 JR Si m p l o t 29 1 27 3 , 3 8 3 , 7 9 5 11 , 4 3 6 , 9 2 2 0 0 0 11 , 4 3 6 , 9 2 2 4. 1 8 3 0. 0 0 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 8, 0 1 5 , 3 6 7 0 0 0 8,0 1 5 , 3 6 7 32 0. 0 0 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 84 , 5 1 6 , 5 0 2 0 0 0 84 , 5 1 6 , 5 0 2 4. 0 3 3 0. 0 0 % 16 To t a l An n u a l Id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 . 2 0 9 , 5 5 2 , 2 0 8 73 6 , 0 6 7 , 1 0 5 0 0 0 73 6 , 0 6 7 , 1 0 5 5. 5 7 2 0.0 0 % 17 5/ 1 6 / 0 2 PC A Ra t e (p r o p o s e d ) 1. 7 2 4 1 ce n t s / k W h 18 10 / 1 / 0 1 PC A Ra t e (e × p i r i n g ) 1. 7 2 4 1 ce n t s / k W h 19 Se c u r i t i z a t i o n 0. 0 0 0 0 ce n t s / k W h Co m m i s s i o n St a f f - Op t i o n No . 3 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 5/ 1 6 / 0 2 PC A Ra t e s to 5/ 1 6 / 0 3 PC A Ra t e s Se c o n d Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s Pr o p o s e d PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Lin e Sc h . Nu m b e r of No r m a l i z e d 5/ 1 6 / 2 0 0 2 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 3 Av e r a g e Pe r c e n t NA Ta r i f f De s c r i p t i o n NE Cu s t o m e r s (k W h } Re v e n u e Ad i u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s Re v e n u e g/ k _ W h Ch a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 28 6 , 1 4 2 , 7 5 5 (6 2 , 9 5 5 , 8 8 9 ) 0 0 22 3 , 1 8 6 , 8 6 6 5. 3 6 4 -2 2 . 0 0 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 21 , 7 3 8 , 8 7 5 (4 , 1 0 0 , 7 5 3 ) O O 17 , 6 3 8 , 1 2 2 6. 5 0 8 -1 8 . 8 6 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 15 0 , 7 3 8 , 7 1 6 (4 3 , 1 8 3 , 0 2 7 ) 0 0 10 7 , 5 5 5 , 6 8 9 3. 7 6 8 -2 8 . 6 5 % 4 Du s k to Da w n Lig h t i n g 15 - 6, 0 1 1 , 8 7 2 1,5 1 7 , 1 7 2 (9 0 , 9 6 0 ) 0 0 1, 4 2 6 , 2 1 2 23 . 7 2 3 -6 . 0 0 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 87 , 5 5 4 , 2 8 1 (2 9 , 3 9 9 , 5 5 3 ) 0 0 58 , 1 5 4 , 7 2 8 2. 9 9 3 -3 3 . 5 8 % 6 tr r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 10 0 , 4 4 7 , 8 3 8 (2 7 , 7 7 7 , 7 9 4 ) 0 0 72 , 6 7 0 , 0 4 4 3. 9 5 8 -2 7 . 6 5 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 , 3 1 0 , 7 1 6 91 8 , 6 7 8 (2 1 6 , 5 2 1 ) O O 70 2 , 1 5 7 4. 9 0 7 -2 3 . 5 7 % 8 Mu n i c i p a l St r e e t Li g h t i n g 41 84 16 , 2 8 8 , 1 8 4 2, 1 2 1 , 3 3 0 (2 4 6 , 4 4 0 ) 0 0 1, 8 7 4 , 8 9 0 11 . 5 1 1 -1 1 . 6 2 % 9 Tr a f f i c Co n t r o l Lig h t i n g 42 56 11 , 9 4 4 , 0 4 2 ;3 7 0 2 9 5 5 8 (1 8 0 , 7 1 3 ) O O 19 0 , 2 4 5 1. 5 9 3 -4 8 . 7 2 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 65 1 , 5 5 0 , 6 0 3 (1 6 8 , 1 5 1 , 6 5 1 ) 0 0 48 3 , 3 9 8 , 9 5 2 4. 3 5 0 -2 5 . 8 1 % Sp e c i a l Co n t r a c t s : 11 Mi c r o n 26 1 56 6 . 1 5 4 , 0 1 2 23 , 6 2 3 , 7 4 4 (8 , 5 6 5 , 9 1 0 ) 0 0 15 , 0 5 7 , 8 3 4 2. 6 6 0 -3 6 . 2 6 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 41 , 4 4 0 , 4 6 9 (1 5 , 9 4 8 , 2 3 0 ) O 0 25 , 4 9 2 , 2 3 9 2. 4 1 8 -3 8 . 4 8 % 13 JR Sim p l o t 29 1 27 3 , 3 8 3 , 7 9 5 11 , 4 3 6 , 9 2 2 (4 , 1 3 6 , 2 9 7 ) 0 0 7, 3 0 0 , 6 2 5 2. 6 7 0 -3 6 . 1 7 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 8, 0 1 5 , 3 6 7 (3 , 0 5 8 , 4 3 7 ) O O 4 95 6 93 0 2. 4 5 2 -3 8 . 1 6 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 84 , 5 1 6 , 5 0 2 (3 1 , 7 0 8 , 8 7 4 ) 0 0 52 , 8 0 7 , 6 2 8 2. 5 2 0 -3 7 . 5 2 % 16 To t a l An n u a l id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 73 6 , 0 6 7 , 1 0 5 (1 9 9 , 8 6 0 , 5 2 5 ) 0 0 53 6 , 2 0 6 , 5 8 0 4. 0 5 9 -2 7 . 1 5 % 17 5/ 1 6 / 0 3 PC A Ra t e (p r o p o s e d ) 0. 2 1 1 1 ce n t s / k W h RM Om 18 5/ 1 6 / 0 2 PC A Ra t e (e × p i r i n g ) 1.7 2 4 1 ce n t s / k W h 19 Se c u r i t i z a t i o n 0. 0 0 0 0 ce n t s / k W h Co m m i s s i o n St a f f - Op t i o n No . 3 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 5/ 1 6 / 0 3 PC A Ra t e s to 5/ 1 6 / 0 4 PC A Ra t e s Th i r d Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s Pr o p o s e d PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Lin e Sc h . Nu m b e r of No r m a l i z e d 5/ 1 6 / 2 0 0 3 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 4 Av e r a g e Pe r c e n t Ta r i f f De s c r i p t i o n No . Cu s t o m e r s Re v e n u e Ad j u s t m e n t s Ad us t m e n t s Ad j u s t m e n t s Re v e n u e g/ k \ W h C_ h a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 22 3 , 1 8 6 , 8 6 6 (8 , 7 8 3 , 8 6 5 ) O 0 21 4 , 4 0 3 , 0 0 0 5. 1 5 3 -3 . 9 4 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 17 , 6 3 8 , 1 2 2 (5 7 2 , 1 5 4 ) O O 17 , 0 6 5 . 9 6 7 6. 2 9 7 -3 . 2 4 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 10 7 , 5 5 5 , 6 8 9 (6 , 0 2 5 , 0 7 4 ) O 0 10 1 , 5 3 0 , 6 1 6 3. 5 5 7 -5 . 6 0 % 4 Du s k to Da w n Li g h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 4 2 6 , 2 1 2 (1 2 , 6 9 1 ) O 0 1, 4 1 3 , 5 2 1 23 . 5 1 2 -0 . 8 9 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 58 , 1 5 4 , 7 2 8 (4 , 1 0 1 , 9 4 7 ) O O 54 , 0 5 2 , 7 8 1 2. 7 8 2 -7 . 0 5 % 6 Ir r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 72 , 6 7 0 , 0 4 4 (3 , 8 7 5 , 6 7 2 ) O O 68 , 7 9 4 , 3 7 1 3. 7 4 7 -5 . 3 3 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 , 3 1 0 , 7 1 6 70 2 , 1 5 7 (3 0 , 2 1 0 ) O O 67 1 , 9 4 7 4. 6 9 5 -4 . 3 0 % 8 Mu n i c i p a l St r e e t Lig h t i n g 41 84 16 , 2 8 8 , 1 8 4 1,8 7 4 , 8 9 0 (3 4 , 3 8 4 ) 0 0 1, 8 4 0 , 5 0 5 11 . 3 0 0 -1 . 8 3 % 9 Tr a f f i c Co n t r o l Li g h t i n g 42 56 11 , 9 4 4 , 0 4 2 19 0 , 2 4 5 (2 5 21 4 ) O 0 16 5 1 3 1 -1 3 . 2 5 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 48 3 , 3 9 8 , 9 5 2 (2 3 , 4 6 1 , 2 1 2 ) 0 0 45 9 , 9 3 7 , 7 4 0 4. 1 3 8 -4 . 8 5 % Sp e c i a l Co n t r a c t s : 11 Mi c r o n 26 1 56 6 , 1 5 4 , 0 1 2 15 , 0 5 7 , 8 3 4 (1 , 1 9 5 , 1 5 1 ) O O 13 , 8 6 2 , 6 8 3 2. 4 4 9 -7 . 9 4 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 25 , 4 9 2 , 2 3 9 (2 , 2 2 5 , 1 6 3 ) O 0 23 , 2 6 7 , 0 7 6 2. 2 0 7 -8 . 7 3 % 13 JR Si m p l o t 29 1 27 3 , 3 8 3 , 7 9 5 7, 3 0 0 , 6 2 5 (5 7 7 , 1 1 3 ) 0 0 6, 7 2 3 , 5 1 2 2. 4 5 9 -7 . 9 0 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 4, 9 5 6 , 9 3 0 (4 2 6 , 7 2 6 ) 0 0 4, 5 3 0 , 2 0 5 2. 2 4 1 -8 . 6 1 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 52 , 8 0 7 , 6 2 8 (4 , 4 2 4 , 1 5 3 ) 0 0 48 , 3 8 3 , 4 7 5 2. 3 0 9 -8 . 3 8 % 16 To t a l An n u a l Id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 53 6 , 2 0 6 , 5 8 0 (2 7 , 8 8 5 , 3 6 5 ) 0 0 50 8 , 3 2 1 , 2 1 5 3. 8 4 8 -5 . 2 0 % 17 5/ 1 6 / 0 4 PC A Ra t e (p r o p o s e d ) 0. 0 0 0 0 ce n t s / k W h 18 5/ 1 6 / 0 3 PC A Ra t e (e x p i r i n g ) 0.2 1 1 1 ce n t s / k W h 2 Ë 19 Se c u r i t i z a t i o n 0. 0 0 0 0 ce n t s / k W h Co m m i s s i o n St a f f - Op t i o n No . 2 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 10 / 1 / 0 1 PC A Ra t e s to 5/ 1 6 / 0 2 PC A Ra t e s Fi r s t Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Li n e Sc h . Nu m b e r of No r m a l i z e d 10 / 1 / 2 0 0 1 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 2 Av e r a g e Pe r c e n t N Ta r i f f De s c r i p t i o n No . Cu s t o m e r s (k W h ) Re v e n u e Ad j u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s Re v e n u e ¢/ k W h Ch a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 28 6 , 1 4 2 , 7 5 5 8, 2 0 9 , 6 4 8 0 0 29 4 , 3 5 2 , 4 0 3 7. 0 7 4 2. 8 7 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 21 , 7 3 8 , 8 7 5 53 4 , 7 5 1 0 0 22 , 2 7 3 , 6 2 6 8. 2 1 8 2. 4 6 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 15 0 , 7 3 8 , 7 1 6 5, 6 3 1 , 2 0 4 0 0 15 6 , 3 6 9 , 9 2 0 5. 4 7 9 3. 7 4 % 4 Du s k to Da w n Li g h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 5 1 7 , 1 7 2 11 , 8 6 1 0 0 1, 5 2 9 , 0 3 3 25 . 4 3 4 0. 7 8 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 87 , 5 5 4 , 2 8 1 3, 8 3 3 , 7 9 5 0 0 91 , 3 8 8 , 0 7 6 4. 7 0 3 4. 3 8 % 6 Ir r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 10 0 , 4 4 7 , 8 3 8 3, 6 2 2 , 3 1 2 0 0 10 4 , 0 7 0 , 1 5 0 5. 6 6 8 3. 6 1 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 , 3 1 0 , 7 1 6 91 8 , 6 7 8 28 , 2 3 5 0 0 94 6 , 9 1 3 6. 6 1 7 3. 0 7 % 8 Mu n i c i p a l St r e e t Li g h t i n g 41 84 16 , 2 8 8 , 1 8 4 2, 1 2 1 , 3 3 0 32 , 1 3 7 0 0 2, 1 5 3 , 4 6 7 13 . 2 2 1 1. 5 1 % 9 Tr a f f i c Co n t r o l Lig h t i n g 42 56 11 , 9 4 4 , 0 4 2 37 0 , 9 5 8 23 , 5 6 6 0 0 39 4 , 5 2 4 3 6. 3 5 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 65 1 , 5 5 0 , 6 0 3 21 , 9 2 7 , 5 0 9 0 0 67 3 , 4 7 8 , 1 1 2 6. 0 6 0 3. 3 7 % Sp e c i a l Co n t r a c t s : 11 Mi c r o n 26 1 56 6 , 1 5 4 , 0 1 2 23 , 6 2 3 , 7 4 4 1, 1 1 7 , 0 2 2 0 0 24 , 7 4 0 , 7 6 6 4. 3 7 0 4. 7 3 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 41 , 4 4 0 , 4 6 9 2, 0 7 9 , 7 0 0 0 0 43 , 5 2 0 , 1 6 9 4. 1 2 9 5. 0 2 % 13 JR Si m p l o t 29 1 27 3 , 3 8 3 , 7 9 5 11 , 4 3 6 , 9 2 2 53 9 , 3 8 6 0 0 11 , 9 7 6 , 3 0 8 4. 3 8 1 4. 7 2 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 8, 0 1 5 , 3 6 7 39 8 , 8 3 0 0 0 8, 4 1 4 , 1 9 7 4 4. 9 8 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 84 , 5 1 6 , 5 0 2 4, 1 3 4 , 9 3 8 0 0 88 , 6 5 1 , 4 4 0 4. 2 3 0 4. 8 9 % 16 To t a l An n u a l id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 73 6 , 0 6 7 , 1 0 5 26 , 0 6 2 , 4 4 7 0 0 76 2 , 1 2 9 , 5 5 2 5. 7 7 0 3. 5 4 % 17 5/ 1 6 / 0 2 PC A Ra t e (p r o p o s e d ) 1. 9 2 1 4 ce n t s / k W h 18 10 / 1 / 0 1 PC A Ra t e (e x p i r i n g ) 1. 7 2 4 1 ce n t s / k W h 19 Se c u r i t i z a t i o n 0. 0 0 0 0 ce n t s / k W h Co m m i s s i o n St a f f - Op t i o n No . 2 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e Im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 5/ 1 6 / 0 2 PC A Ra t e s to 5/ 1 6 / 0 3 PC A Ra t e s Se c o n d Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s Pr o p o s e d PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Lin e Sc h . Nu m b e r of No r m a l i z e d 5/ 1 6 / 2 0 0 2 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 3 Av e r a g e Pe r c e n t No . Ta r i f f De s c r i p t i o n N_ o . Cu s t o m e r s (k W h ) Re v e n u e Ad j u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s Re v e n u e ¢/ R Ch a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 29 4 , 3 5 2 , 4 0 3 (7 9 , 9 4 9 , 4 0 3 ) 0 0 21 4 , 4 0 3 , 0 0 0 5. 1 5 3 -2 7 . 1 6 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 22 , 2 7 3 , 6 2 6 (5 , 2 0 7 , 6 5 9 ) 0 0 17 , 0 6 5 , 9 6 7 6. 2 9 7 -2 3 . 3 8 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 15 6 , 3 6 9 , 9 2 0 (5 4 , 8 3 9 , 3 0 4 ) O 0 10 1 , 5 3 0 , 6 1 6 3. 5 5 7 -3 5 . 0 7 % 4 Du s k to Da w n Li g h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 5 2 9 , 0 3 3 (1 1 5 , 5 1 2 ) 0 0 1, 4 1 3 , 5 2 1 23 . 5 1 2 -7 . 5 5 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 91 , 3 8 8 , 0 7 6 (3 7 , 3 3 5 , 2 9 5 ) 0 0 54 , 0 5 2 , 7 8 1 2. 7 8 2 -4 0 . 8 5 % 6 Ir r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 10 4 , 0 7 0 , 1 5 0 (3 5 , 2 7 5 , 7 7 9 ) 0 0 68 , 7 9 4 , 3 7 1 3. 7 4 7 -3 3 . 9 0 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 . 3 1 0 , 7 1 6 94 6 , 9 1 3 (2 7 4 , 9 6 6 ) 0 0 67 1 , 9 4 7 4. 6 9 5 -2 9 . 0 4 % 8 Mu n i c i p a l St r e e t Lig h t i n g 41 84 16 , 2 8 8 , 1 8 4 2, 1 5 3 , 4 6 7 (3 1 2 , 9 6 1 ) 0 0 1, 8 4 0 , 5 0 5 11 . 3 0 0 -1 4 . 5 3 % 9 Tr a f f i c Co n t r o l Li g h t i n g 42 56 11 , 9 4 4 , 0 4 2 39 4 , 5 2 4 (2 2 9 , 4 9 3 ) 0 0 16 5 & _ 3 1 m -5 8 . 1 7 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 67 3 , 4 7 8 , 1 1 2 (2 1 3 , 5 4 0 , 3 7 1 ) 0 0 45 9 , 9 3 7 , 7 4 0 4. 1 3 8 -3 1 . 7 1 % Sp e c i a l Co n t r a c t s : 11 Mic r o n 26 1 56 6 , 1 5 4 , 0 1 2 24 , 7 4 0 , 7 6 6 (1 0 , 8 7 8 , 0 8 3 ) 0 0 13 , 8 6 2 , 6 8 3 2. 4 4 9 -4 3 . 9 7 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 43 , 5 2 0 , 1 6 9 (2 0 , 2 5 3 , 0 9 3 ) 0 0 23 , 2 6 7 , 0 7 6 2. 2 0 7 -4 6 . 5 4 % 13 JR Si m p \ o t 29 1 27 3 , 3 8 3 , 7 9 5 11 , 9 7 6 , 3 0 8 (5 , 2 5 2 , 7 9 6 ) 0 0 6, 7 2 3 , 5 1 2 2. 4 5 9 -4 3 . 8 6 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 8, 4 1 4 , 1 9 7 (3 , 8 8 3 , 9 9 2 ) 0 0 4. 5 3 0 . 2 0 5 2. 2 4 1 -4 6 . 1 6 % 15 Su b - T o t a \ 4 2, 0 9 5 , 7 6 1 , 6 7 8 88 , 6 5 1 , 4 4 0 (4 0 , 2 6 7 , 9 6 5 ) 0 0 48 , 3 8 3 , 4 7 5 2. 3 0 9 -4 5 . 4 2 % 16 To t a l An n u a l Id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 76 2 , 1 2 9 , 5 5 2 (2 5 3 , 8 0 8 , 3 3 6 ) 0 0 50 8 , 3 2 1 , 2 1 5 3. 8 4 8 -3 3 . 3 0 % 17 5/ 1 6 / 0 3 PC A Ra t e (p r o p o s e d ) 0. 0 0 0 0 ce n t s / k W h 18 5/ 1 6 / 0 2 PC A Ra t e (e x p i r i n g ) 1. 9 2 1 4 ce n t s / k W h 19 Se c u r i t i z a t i o n 0. 0 0 0 0 ce n t s / k W h Co m m i s s i o n St a f f - Op t i o n No . 1 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 10 / 1 / 0 1 PC A Ra t e s to 5/ 1 6 / 0 2 PC A Ra t e s Fi r s t Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Li n e Sc h . Nu m b e r of No r m a l i z e d 10 / 1 / 2 0 0 1 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 2 Av e r a g e Pe r c e n t NA Ta r i f f De s c r i p t i o n & _C u s t o m e r s (k W h ) Re v e n u e Ad j u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s Re v e n u e g/ k W h Ch a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 28 6 , 1 4 2 , 7 5 5 (4 3 , 7 2 3 , 7 6 0 ) 23 , 3 0 1 , 5 8 5 0 26 5 , 7 2 0 , 5 8 0 6. 3 8 6 -7 . 1 4 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 21 , 7 3 8 , 8 7 5 (2 , 8 4 8 , 0 3 2 ) 1, 5 1 7 , 7 9 4 0 20 , 4 0 8 , 6 3 7 7. 5 3 0 -6 . 1 2 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 15 0 , 7 3 8 , 7 1 6 (2 9 , 9 9 1 , 2 2 6 ) 15 , 9 8 3 , 1 4 3 0 13 6 , 7 3 0 , 6 3 3 4. 7 9 1 -9 . 2 9 % 4 Du s k to Da w n Li g h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 5 1 7 , 1 7 2 (6 3 , 1 7 3 ) 33 , 6 6 6 0 1, 4 8 7 , 6 6 6 24 . 7 4 5 -1 . 9 4 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 87 , 5 5 4 , 2 8 1 (2 0 , 4 1 8 , 4 0 7 ) 10 , 8 8 1 , 5 2 6 0 78 , 0 1 7 , 4 0 0 4. 0 1 5 -1 0 . 8 9 % 6 Ir r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 10 0 , 4 4 7 , 8 3 8 (1 9 , 2 9 2 , 0 7 3 ) 10 , 2 8 1 , 2 7 2 0 91 , 4 3 7 , 0 3 7 4. 9 8 0 -8 . 9 7 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 , 3 1 0 , 7 1 6 91 8 , 6 7 8 (1 5 0 , 3 7 7 ) 80 , 1 4 0 0 84 8 , 4 4 1 5. 9 2 9 -7 . 6 5 % 8 Mu n i c i p a l St r e e t Li g h t i n g 41 84 16 , 2 8 8 , 1 8 4 2, 1 2 1 , 3 3 0 (1 7 1 , 1 5 6 ) 91 , 2 1 4 0 2, 0 4 1 , 3 8 8 12 . 5 3 3 -3 . 7 7 % 9 Tr a f f i c Co n t r o l Li g h t i n g 42 5_ 6 11 , 9 4 4 , 0 4 2 37 0 , 9 5 8 (1 2 5 , 5 0 8 ) 66 , 8 8 7 0 31 2 , 3 3 7 2. 6 1 5 -1 5 . 8 0 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 65 1 , 5 5 0 , 6 0 3 (1 1 6 , 7 8 3 , 7 1 1 ) 62 , 2 3 7 , 2 2 7 0 59 7 , 0 0 4 , 1 1 9 5. 3 7 2 -8 . 3 7 % Sp e c i a l Co n t r a c t s : 11 Mi c r o n 26 1 56 6 , 1 5 4 , 0 1 2 23 , 6 2 3 , 7 4 4 (5 , 9 4 9 , 1 4 6 ) 3, 1 7 0 , 4 6 2 0 20 , 8 4 5 , 0 6 0 3. 6 8 2 -1 1 . 7 6 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 41 , 4 4 0 , 4 6 9 (1 1 , 0 7 6 , 2 7 3 ) 5, 9 0 2 , 8 4 8 0 36 , 2 6 7 , 0 4 4 3. 4 4 1 -1 2 . 4 8 % 13 JR Si m p l o t 29 1 27 3 , 3 8 3 , 7 9 5 11 , 4 3 6 , 9 2 2 (2 , 8 7 2 , 7 1 7 ) 1, 5 3 0 , 9 4 9 0 10 , 0 9 5 , 1 5 4 3. 6 9 3 -1 1 . 7 3 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 8, 0 1 5 , 3 6 7 (2 12 4 . . 1 2 8 ) 1, 1 3 2 , 0 0 6 0 7, 0 2 3 , 2 4 5 3. 9 4 -1 2 . 3 8 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 84 , 5 1 6 , 5 0 2 (2 2 , 0 2 2 , 2 6 4 ) 11 , 7 3 6 , 2 6 5 0 74 , 2 3 0 , 5 0 4 3. 5 4 2 -1 2 . 1 7 % 16 To t a l An n u a l id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 73 6 , 0 6 7 , 1 0 5 (1 3 8 , 8 0 5 , 9 7 5 ) 73 , 9 7 3 , 4 9 2 0 67 1 , 2 3 4 , 6 2 3 5. 0 8 1 -8 . 8 1 % 17 5/ 1 6 / 0 2 PC A Ra t e (p r o p o s e d ) 0. 6 7 3 3 ce n t s / k W h t ? 18 10 / 1 / 0 1 PC A Ra t e (e × p i r i n g ) 1. 7 2 4 1 ce n t s / k W h 19 Se c u r i t i z a t i o n Ra t e 0. 5 6 0 0 ce n t s / k W h Co m m i s s i o n St a f f - Op t i o n No . 1 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 5/ 1 6 / 0 2 PC A Ra t e s to 5/ 1 6 / 0 3 PC A Ra t e s Se c o n d Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s Pr o p o s e d PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Li n e Sc h . Nu m b e r of No r m a l i z e d 5/ 1 6 / 2 0 0 2 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 3 Av e r a g e Pe r c e n t N Ta r i f f De s c r i p t i o n & Cu s t o m e r s (k W h ) Re v e n u e Ad j u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s Re v e n u e 4/ k W h Ch a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 26 5 , 7 2 0 , 5 8 0 (2 8 , 0 1 5 , 9 9 5 ) (4 , 6 7 2 , 8 0 0 ) 0 23 3 , 0 3 1 , 7 8 5 5. 6 0 0 -1 2 . 3 0 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 20 , 4 0 8 , 6 3 7 (1 , 8 2 4 , 8 7 6 ) (3 0 4 , 3 7 2 ) 0 18 , 2 7 9 , 3 8 9 6. 7 4 4 -1 0 . 4 3 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 13 6 , 7 3 0 , 6 3 3 (1 9 , 2 1 6 , 8 7 5 ) (3 , 2 0 5 , 1 9 1 ) 0 11 4 , 3 0 8 , 5 6 7 4. 0 0 5 -1 6 . 4 0 % 4 Du s k to Da w n Li g h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 4 8 7 , 6 6 6 (4 0 , 4 7 8 ) (6 , 7 5 1 ) 0 1, 4 4 0 , 4 3 6 23 . 9 6 0 -3 . 1 7 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 78 , 0 1 7 , 4 0 0 (1 3 , 0 8 3 , 0 9 2 ) (2 , 1 8 2 , 1 3 5 ) O 62 , 7 5 2 , 1 7 3 3. 2 2 9 -1 9 . 5 7 % 6 Ir r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 91 , 4 3 7 , 0 3 7 (1 2 , 3 6 1 , 3 9 4 ) (2 , 0 6 1 , 7 6 2 ) 0 77 , 0 1 3 , 8 8 1 4. 1 9 5 -1 5 . 7 7 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 , 3 1 0 , 7 1 6 84 8 , 4 4 1 (9 6 , 3 5 4 ) (1 6 , 0 7 1 ) 0 73 6 , 0 1 6 5. 1 4 3 -1 3 . 2 5 % 8 Mu n i c i p a l St r e e t Li g h t i n g 41 84 16 , 2 8 8 , 1 8 4 2, 0 4 1 , 3 8 8 (1 0 9 , 6 6 8 ) (1 8 , 2 9 2 ) 0 1, 9 1 3 , 4 2 8 11 . 7 4 7 -6 . 2 7 % 9 Tr a f f i c Co n t r o l Lig h t i n g 42 56 11 , 9 4 4 , 0 4 2 31 2 , 3 3 7 (8 0 , 4 1 9 ) (1 3 . 4 1 3 ) 0 21 8 , 5 0 4 11 L 2 9 -3 0 . 0 4 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 59 7 , 0 0 4 , 1 1 9 (7 4 , 8 2 9 , 1 5 2 ) (1 2 , 4 8 0 , 7 8 7 ) 0 50 9 , 6 9 4 , 1 8 1 4. 5 8 6 -1 4 . 6 2 % Sp e c i a l Co n t r a c t s : 11 Mi c r o n 26 1 56 6 , 1 5 4 , 0 1 2 20 , 8 4 5 , 0 6 0 (3 , 8 1 1 , 9 1 5 ) (6 3 5 , 7 9 1 ) 0 16 , 3 9 7 , 3 5 4 2. 8 9 6 -2 1 . 3 4 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 36 , 2 6 7 , 0 4 4 (7 , 0 9 7 , 1 2 1 ) (1 , 1 8 3 , 7 3 2 ) 0 27 , 9 8 6 , 1 9 2 2. 6 5 5 -2 2 . 8 3 % 13 JR Si m p l o t 29 1 27 3 , 3 8 3 , 7 9 5 10 , 0 9 5 , 1 5 4 (1 , 8 4 0 , 6 9 3 ) (3 0 7 , 0 1 0 ) 0 7, 9 4 7 , 4 5 1 2. 9 0 7 -2 1 . 2 7 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 _7 , 0 2 4 2 4 5 (1 , 3 6 1 , 0 3 5 ) (2 2 7 3 0 8 ) 0 5. 4 3 5 , 2 0 3 2& 8 9 -2 2 . 6 1 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 74 , 2 3 0 , 5 0 4 (1 4 , 1 1 0 , 7 6 3 ) (2 , 3 5 3 , 5 4 0 ) 0 57 , 7 6 6 , 2 0 0 2. 7 5 6 -2 2 . 1 8 % 16 To t a l An n u a l id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 67 1 , 2 3 4 , 6 2 3 (8 8 , 9 3 9 , 9 1 5 ) (1 4 , 8 3 4 , 3 2 7 ) 0 56 7 , 4 6 0 , 3 8 1 4. 2 9 6 -1 5 . 4 6 % 17 5/ 1 6 / 0 3 PC A Ra t e (p r o p o s e d ) 0. 0 0 0 0 ce n t s / k W h 18 5/ 1 6 / 0 2 PC A Ra t e (e x p i r i n g ) 0. 6 7 3 3 ce n t s / k W h 19 Se c u r i t i z a t i o n Ra t e (0 . 1 1 2 3 ) ce n t s / k W h 0. 4 4 7 7 - 0. 5 6 0 0 = -0 . 1 1 2 3 Co m m i s s i o n St a f f - Op t i o n No . 1 iP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 5/ 1 6 / 0 3 PC A Ra t e s to 5/ 1 6 / 0 4 PC A Ra t e s Th i r d Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r g e 20 0 0 Sa l e s Pr o p o s e d PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Lin e Sc h . Nu m b e r of No r m a l i z e d 5/ 1 6 / 2 0 0 3 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 4 Av e r a g e Pe r c e n t No . Ta r i f f De s c r i p t i o n No . Cu s t o m e r s (k W h ) Re v e n u e Ad j u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s Re v e n u e ¢/ k W h Ch a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 23 3 , 0 3 1 , 7 8 5 0 (4 5 , 7 7 1 ) 0 23 2 , 9 8 6 , 0 1 4 5. 5 9 9 -0 . 0 2 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 18 , 2 7 9 , 3 8 9 0 (2 , 9 8 1 ) 0 18 , 2 7 6 , 4 0 8 6. 7 4 3 -0 . 0 2 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 11 4 , 3 0 8 , 5 6 7 0 (3 1 , 3 9 5 ) 0 11 4 , 2 7 7 , 1 7 2 4. 0 0 4 -0 . 0 3 % 4 Du s k to Da w n Li g h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 4 4 0 , 4 3 6 0 (6 6 ) 0 1, 4 4 0 , 3 7 0 23 . 9 5 9 0. 0 0 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 62 , 7 5 2 , 1 7 3 0 (2 1 , 3 7 4 ) 0 62 , 7 3 0 , 7 9 9 3. 2 2 8 -0 . 0 3 % 6 Ir r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 77 , 0 1 3 , 8 8 1 0 (2 0 , 1 9 5 ) 0 76 , 9 9 3 , 6 8 6 4. 1 9 4 -0 . 0 3 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 , 3 1 0 , 7 1 6 73 6 , 0 1 6 0 (1 5 7 ) 0 73 5 , 8 5 9 5. 1 4 2 -0 . 0 2 % 8 Mu n i c i p a l St r e e t Li g h t i n g 41 84 16 , 2 8 8 , 1 8 4 1, 9 1 3 , 4 2 8 0 (1 7 9 ) 0 1, 9 1 3 , 2 4 8 11 . 7 4 6 -0 . 0 1 % 9 Tr a f f i c Co n t r o l Li g h t i n g 42 _5 6 11 _ 9 4 4 & 4 2 2_ i f L 5 0 4 0 (1 . 3 1 ) 0 21 8 1 3 1. 8 2 8 -0 . 0 6 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 50 9 , 6 9 4 , 1 8 1 0 (1 2 2 , 2 5 2 ) 0 50 9 . 5 7 1 , 9 2 9 4. 5 8 5 -0 . 0 2 % Sp e c i a l Co n t r a c t s : 11 Mic r o n 26 1 56 6 , 1 5 4 , 0 1 2 16 , 3 9 7 , 3 5 4 0 (6 , 2 2 8 ) 0 16 , 3 9 1 , 1 2 6 2. 8 9 5 -0 . 0 4 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 27 , 9 8 6 , 1 9 2 0 (1 1 , 5 9 5 ) 0 27 , 9 7 4 , 5 9 7 2. 6 5 4 -0 . 0 4 % 13 JR Si m p l o t 29 1 27 3 , 3 8 3 , 7 9 5 7, 9 4 7 , 4 5 1 0 (3 , 0 0 7 ) 0 7, 9 4 4 , 4 4 4 2. 9 0 6 -0 . 0 4 % 14 DO E 30 1 2_ 0 2 2 1 _ 4 3 , 8 7 1 5, 4 3 5 , 2 0 3 0 (2 . 2 2 4 ) O 5, 4 3 2 , 9 7 9 2. 6 8 8 -0 . 0 4 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 57 , 7 6 6 . 2 0 0 0 (2 3 , 0 5 3 ) 0 57 , 7 4 3 , 1 4 7 2. 7 5 5 -0 . 0 4 % 16 To t a \ An n u a l Id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 56 7 , 4 6 0 , 3 8 1 0 (1 4 5 , 3 0 5 ) 0 56 7 , 3 1 5 , 0 7 6 4. 2 9 5 -0 . 0 3 % 17 5/ 1 6 / 0 4 PC A Ra t e (p r o p o s e d ) 0. 0 0 0 0 ce n t s / k W h 18 5/ 1 6 / 0 3 PC A Ra t e (e x p i r i n g ) 0. 0 0 0 0 ce n t s / k W h 19 Se c u r i t i z a t i o n Ra t e (0 . 0 0 1 1 ) ce n t s / k W h 0. 4 4 6 6 - 0. 4 4 7 7 = -0 . 0 0 1 1 Co m m i s s i o n St a f f - Op t i o n No . 1 IP C - E - 0 2 - 2 & 3 Su m m a r y of Re v e n u e im p a c t St a t e of Id a h o No r m a l i z e d 12 - M o n t h s En d i n g De c e m b e r 31 , 20 0 0 5/ 1 6 / 0 4 PC A Ra t e s to 5/ 1 6 / 0 5 PC A Ra t e s Fo u r t h Ye a r (1 ) (2 ) (3 ) (4 ) (5 ) (6 ) (7 ) (8 ) (9 ) (1 0 ) Ra t e Av e r a g e 20 0 0 Sa l e s Pr o p o s e d PC A Se c u r i t i z a t i o n DS M Pr o p o s e d Li n e Sc h . Nu m b e r of No r m a l i z e d 5/ 1 6 / 2 0 0 4 Re v e n u e Re v e n u e Ri d e r 5/ 1 6 / 2 0 0 5 Av e r a g e Pe r c e n t No . Ta r i f f De s c r i p t i o n NA Cu s t o m e r s (k W h ) Re v e n u e Ad j u s t m e n t s Ad j u s t m e n t s Ad j u s t m e n t s Re v e n u e ¢/ k W h Ch a n g e Un i f o r m Ta r i f f Ra t e s : 1 Re s i d e n t i a l Se r v i c e 1 29 9 , 3 2 1 4, 1 6 0 , 9 9 7 , 3 2 0 23 2 , 9 8 6 , 0 1 4 0 (1 8 , 5 8 3 , 0 1 4 ) 0 21 4 , 4 0 3 , 0 0 0 5. 1 5 3 -7 . 9 8 % 2 Sm a l l Ge n e r a l Se r v i c e 7 30 , 2 3 6 27 1 , 0 3 4 , 5 9 9 18 , 2 7 6 , 4 0 8 0 (1 , 2 1 0 , 4 4 1 ) 0 17 , 0 6 5 , 9 6 7 6. 2 9 7 -6 . 6 2 % 3 La r g e Ge n e r a l Se r v i c e 9 14 , 2 8 7 2, 8 5 4 , 1 3 2 , 6 1 9 11 4 , 2 7 7 , 1 7 2 0 (1 2 , 7 4 6 , 5 5 6 ) 0 10 1 , 5 3 0 , 6 1 6 3. 5 5 7 -1 1 . 1 5 % 4 Du s k to Da w n Li g h t i n g 15 - 6, 0 1 1 , 8 7 2 1, 4 4 0 , 3 7 0 0 (2 6 , 8 4 9 ) 0 1, 4 1 3 , 5 2 1 23 . 5 1 2 -1 . 8 6 % 5 La r g e Po w e r Se r v i c e 19 10 1 1, 9 4 3 , 1 2 9 , 7 2 4 62 , 7 3 0 , 7 9 9 0 (8 , 6 7 8 , 0 1 7 ) 0 54 , 0 5 2 , 7 8 1 2. 7 8 2 -1 3 . 8 3 % 6 Ir r i g a t i o n Se r v i c e 24 12 , 3 4 3 1, 8 3 5 , 9 4 1 , 4 5 4 76 , 9 9 3 , 6 8 6 0 (8 , 1 9 9 , 3 1 5 ) 0 68 , 7 9 4 , 3 7 1 3. 7 4 7 -1 0 . 6 5 % 7 Un m e t e r e d Ge n e r a l Se r v i c e 40 80 6 14 , 3 1 0 , 7 1 6 73 5 , 8 5 9 0 (6 3 , 9 1 2 ) 0 67 1 , 9 4 7 4. 6 9 5 -8 . 6 9 % 8 Mu n i c i p a l St r e e t Li g h t i n g 41 84 16 , 2 8 8 , 1 8 4 1, 9 1 3 , 2 4 8 0 (7 2 , 7 4 3 ) 0 1, 8 4 0 , 5 0 5 11 . 3 0 0 -3 . 8 0 % 9 Tr a f f i c Co n t r o l Li g h t i n g 42 56 11 , 9 4 4 , 0 4 2 21 8 , 3 7 3 0 (5 3 , 3 4 2 ) 0 16 5 , 0 3 1 1. 3 ] L 2 -2 4 . 4 3 % 10 Su b - T o t a l 35 7 , 2 3 4 11 , 1 1 3 , 7 9 0 , 5 3 0 50 9 , 5 7 1 , 9 2 9 0 (4 9 , 6 3 4 , 1 8 9 ) 0 45 9 , 9 3 7 , 7 4 0 4. 1 3 8 -9 . 7 4 % SR e È L I Co n t r a c t s 11 Mi c r o n 26 1 56 6 , 1 5 4 , 0 1 2 16 , 3 9 1 , 1 2 6 0 (2 , 5 2 8 , 4 4 4 ) 0 13 , 8 6 2 , 6 8 3 2. 4 4 9 -1 5 . 4 3 % 12 FM C 28 1 1, 0 5 4 , 0 8 0 , 0 0 0 27 , 9 7 4 , 5 9 7 0 (4 , 7 0 7 , 5 2 1 ) 0 23 , 2 6 7 , 0 7 6 2. 2 0 7 -1 6 . 8 3 % 13 JR Si m p l o t 29 1 27 3 , 3 8 3 , 7 9 5 7, 9 4 4 , 4 4 4 0 (1 , 2 2 0 , 9 3 2 ) 0 6, 7 2 3 , 5 1 2 2. 4 5 9 -1 5 . 3 7 % 14 DO E 30 1 20 2 , 1 4 3 , 8 7 1 5, 4 3 2 , 9 7 9 0 (9 0 2 , 7 7 5 ) 0 4, 5 3 0 , 2 0 5 2. 2 4 1 -1 6 . 6 2 % 15 Su b - T o t a l 4 2, 0 9 5 , 7 6 1 , 6 7 8 57 , 7 4 3 , 1 4 7 0 (9 , 3 5 9 , 6 7 2 ) 0 48 , 3 8 3 , 4 7 5 2. 3 0 9 -1 6 . 2 1 % 16 To t a i An n u a l Id a h o Re t a i l Sa l e s 35 7 , 2 3 8 13 , 2 0 9 , 5 5 2 , 2 0 8 56 7 , 3 1 5 , 0 7 6 0 (5 8 , 9 9 3 , 8 6 0 ) 0 50 8 , 3 2 1 , 2 1 5 3. 8 4 8 -1 0 . 4 0 % 17 5/ 1 6 / 0 5 PC A Ra t e (p r o p o s e d ) 0. 0 0 0 0 ce n t s / k W h 18 5/ 1 6 / 0 4 PC A Ra t e (e x p i r i n g ) 0. 0 0 0 0 ce n t s / k W h 19 Se c u r i t i z a t i o n Ra t e (0 . 4 4 6 6 ) ce n t s / k W h =0 - 0. 4 4 6 6 = -0 . 4 4 6 6 COMPARISON OF COST RECOVERY OPTIONSRecoveryof2002PCACosts. Case No.IPC-E-02-2&3 Option No.1 Option No.2 Option No.3 Option No.4DescriptionCompanyStaffStaffStaffSecuritizationOneYearFirstYearFirstYearProposalRecoveryNoincrease9.6%DecreasewithwithoutwithoutwithoutStaffTrue-Up Securitization Securitization Securitization(Million$)(Million $)(Million$)(Million $) 2002 PCA Year (First Year) PCA Forecast 28.5 28.5 28.5 28.5True-Up 60.4 207.3 181.2 110.7Oct.1,2001 PCA Balance 0.0 18.0 18.0 18.0Securitization True-Up 51.6 0.0 0.0 0.0Oct.1,2001 PCA Balance 6.3 0.0 0.0 0.0Bondinginterest6.3 0.0 0.0 0.0CostofBonding3.3 0.0 0.0 0.0Total156.4 253.8 227.7 157.2 2003 PCA Year (Second Year) PCA Forecast 0.0 0.0 0.0 0.0True-Up 0.0 0.0 0.0 0.0Oct.1,2001 PCA Balance 0.0 0.0 0.0 0.0Carry-Over 0.0 0.0 26.1 96.6Carry-Over interest 0.0 0.0 1.8 6.8Securitization True-Up 46.4 0.0 0,0 0.0Oct.1,2001 PCA Balance 5.7 0.0 0.0 0.0Bondinginterest3.9 0.0 0.0 0.0CostofBonding3.0 0.0 0.0 0.0Total59.0 0.0 27.9 103.4 2004 PCA Year (Third Year) PCA Forecast 0.0 0.0 0.0 0.0True-Up 0.0 0.0 0.0 0.0Oct.1,2001 PCA Balance 0.0 0.0 0.0 0.0Carry-Over 0.0 0.0 0.0 0.0Carry-Over Interest 0.0 0.0 0.0 0.0Securitization True-Up 49.0 0.0 0.0 0.0Oct.1,2001 PCA Balance 6.0 0.0 0.0 0.0Bondinginterest1.7 0.0 0.0 0.0CostofBonding3.1 0.0 0.0 0.0Total59.8 0.0 0.0 0.0 2002 -2004 PCA Year Totals PCA Forecast 28.5 28.5 28.5 28.5True-Up 60.4 207.3 181.2 110.7Oct.1,2001 PCA Balance 0.0 18.0 18.0 18.0Carry-Over 0.0 0.0 26.1 96.6Carry-Over Interest 0.0 0.0 1.8 6.8Securitization True-Up 147.0 0.0 0.0 0.0Oct.1,2001 PCA Balance 18.0 0.0 0.0 0.0BondingInterest11.9 0.0 0.0 0.0CostofBonding9.4 0.0 0.0 0.0Total275.2 253.8 255.6 260.6 Cost Without Interest and Bonding 253.8 253.8 253.8 253.8 Exhibit No.105 Case Nos.IPC-E-02-2 IPC-E-02-3 K.Hessing,Staff 4/22/02 2001 -2002 TRUE-UP CALCULATIONS FOR IDAHO POWERCOMPANY PCACASENO.IPC-E-02-2 &3 Staff CaseJunsdictionalAllocationFactor85.0% Shanng Percentage 90.0% Line No DESCRIPTION MAR APR MAY JUN JUL AUG SEPT OCT 1 PCA Revenue 2 Normahzed Firm Load MWh 1.106,080 991,176 1.033.117 1.143.545 1,352,219 1.422.263 1.206.799 1.112.3983PCAComponentRatem/KWh1.8321.8323.8613.861 3.861 3.861 3.861 3.8614RevenueAllocatedat85.0%$1.722.387.78 1,543,459.27 3,390,535.03 3,752,943.16 4.437,779.93 4.667 653.83 3.960,533.30 3.650.723.38 5 Load Change Adjustment 6 Actual Firm Loaa MWh 1,144.140 1,099,682 1,270.223 1,441.473 1,508,747 1,522,447 1.185.500 1.128.1747NormalizedFirmLoaaMWh1,106.080 991.176 1,033.117 1.143.545 1,352.219 1.422.2ô3 1,206.799 1.112.3988LoadChangeMWh38.060 108.506 237.106 297.928 156.528 100,184 (21.299 15.7769ExpenseAdjustment(@16.84)5 (640,930 40)(2.323,929 68)(3.992.865.04)(5.017.107.52)(2,635,931.52)(1.687.098 56)358.675.16 (265.667 84) 10 Non-QF PCA 11 m 12 Purchased Water $0 0 0 0 0 0 0 013imgâtionLoadReductionSO.00 0 00 8.649,051.29 11,329.014.63 18.087.054.09 23,159,654.05 14.726.511.42 11.549.423 0914Irr.Reduced Revenue Adj.3 (1,805,493.44)(2,930,802.91)(1,868,809.78)(4,026,084.07)(2.157.862.06)(1,953,973 71)15 Astans Load reduction $0.00 7,537,706 09 7,230.985.80 7,581.563.60 9,659.244.04 12,155,326.00 10.410.225.25 8.442.058 2616MobileGeneraten50.00 0 00 1.147.773.39 25.694.76 1,194,966.08 760.179.86 1.394.431.92 724,227 6417MobileGenerationAdjustmanSo.oo o 00 (3,619.453.00)(213,210.00)0.00 0.00 0.00 0 0018MasterMetenngCostsS0.00 0 00 0.00 9.119.41 (9,119.41)0.00 0.00 0 0019FuelExpense-Coal $7.981,847.61 6,449.302 31 7,085.494.42 8 852.815.81 9,318,032.28 8.463,943.09 6 768,166.62 7.651.353 8120FuelExpense-Gas 5 0.00 0 00 0.00 0.00 238,000.00 244 400.00 255.406.20 288.879 8321FuelExpense.Gas Adj.5 0.00 0 00 __0.00 0.00 (245 935.40)(664,989.40)(190.401.60)0 0022Non-Finn Purchases 5 23,797.993.49 27.531.814 47 39.544,150,89 53 042 176.58 55.013 781.29 45,317 057 05 34,270,507 16 1,158.901 1023QuantifiedPurchasefromBPA50.00 0 00 0.00 0.00 0.00 0 00 0 00 1.148,546 0024SurplusSales5(37,298.223.85)(32.471.710 45)(15,652.344.29)(6 494 508.93)(29 581 147.87)(31,151.673 01)(25.075.683 68)(3.856,653 63)25 FMC Second Block Revenue 5 0.00 0 00 0.00 0.00 0.00 0 00 0 00 0 0026ExpenseAdjustment(@16.84)5 (640.930.40)(2.323,929 68)(3,992 865.04)(5 017 107.52)(2 635 931.52)(1.687.098 56)358.675 16 (265.667 84127SuTotal$(6,159.313.15)6,723.182 74 38,587.300.02 66 184.755.43 59 170.133.80 52.570.715.01 40.759.976 39 24.887.094 55 28 g 29 Fuel Expense 5 4.737,000.00 3,341.000 00 2,293.000 00 2 843,000.00 5 076 000.00 6,445.000 00 5 587.000 00 6.026.000 0030Non-Firm Purchases 5 296.000.00 339,000 00 1.356,000 00 1 872.000.00 2 473.000.00 1.252,000 00 615,000 00 162.000 0031SurplusSales5(2.742,000.00)(3.195.000 00)(597.000 00)(208,000.00)(142.000.00)(595.000 00)(1 570.000 00)(3.022.000 00)32 FMC Second Block Revenue $(889,475.62)(826.062 77)(979,683 11)(693.150.51)(600,808.00)(745,141 45)(664,245 01)(742,239 84)33 Sub-Total 5 1,401.524.38 (341.062 77)2.072,316 89 3,813.849.49 6,806,192.00 6,356.858 55 3.967.754 99 2.423.760.16 34 Change From Base $(7,560.837.53)7,064.245 51 36.514.983 13 62,370.905.94 52.363,941.80 46,213.856 46 36,792.221 40 22.463.334 39 35 Deferral (Shared and Alk)cated)5 (5 784,040 71)5.404.147 82 27.933.962 09 47.713,743.04 40.058.415.48 35,353.600 19 28,146.049 37 17,184.450 81 36 QF Deferral 37 Actual (incl.Meridian Amort )S 3.306.678 92 4,026.364 88 5,245.969.28 2,913.629.58 5.787.563.41 5.480.578 78 4,342,464 83 3.160.426 0638Base31314.445 00 2.038.265 00 3.024.735.00 5.108.325.00 5.317.475.00 5.059.785 00 3.531,295 00 2,438,425 0039ChangeFromBase$1,992,233 92 1,988 099 88 2,221.234.28 (2.194.695.42)470.088.41 420.793 78 811.169 83 722.001 06 40 Quantified Benefit from BPA $0 00 0 00 0.00 0.00 0.00 0 00 0 00 95,049 00 41 Total Non-shared Deferral $1.992.233 92 1,988 099 88 2.221.234.28 (2 194.695.42)470.088.41 420.793.78 811.169 83 817.050 06 42 DeferTal (Allocated)5 1.693.398 83 1.689 884 90 1.888 049.14 (1 865.491 11)399,575.15 357,674.71 689.494 36 694.492 55 43 Mobile Home Metenng Costs 5 0 00 0 00 0.00 0 00 18,637.71 10.450.05 10.183 67 6.640 6444IntemenorFunding$000 000 0.00 000 9,661,84 20.134.19 0.00 0.0045CreditFmmIDACORPEnergy50000000.00 0 00 (166.666.67)(166.666.67)(166.666.67)(166.666.67) 46 Total Deferral $(5.813.029 65)5.550 573 45 26.431 476.21 42.095,308 78 35.881.843.58 30.907,538.65 24 718.527.43 14.068.193.95 47 Principal Balances 48 Beginning Balance 5 0 00 (5.813 029 65)(262 456 21)26.169,020 00 68.264,328.78 104.146,172.36 135 053,711.01 159,772.238.43 49 Amount Deferred $(5.813,029 65)5.550 573 45 26.431,476 21 42,095.308 78 35,881,843.58 30.907.538.65 24 718.527.43 14.068,193.95 50 Ending Balance $(5,813.029 65)(262 456 21)26.169.020 00 68.264,328 76 104.146,172 36 135,053.711.01 159 772.238.43 173.840,432.39 51 Interest Balances 52 Accrual thru Pnor Month 5 0 00 0.00 (42.626 42)(36.824 61)94.020 49 425,401.91 934.960.06 1,610,413.25 53 interest @ 6%per Year $0 00 (29065.15)(1,312 28)130.845 10 341.321 64 520.730.86 675,268.56 798.861.1954PnorMonth's Interest Adi.5 0 00 (13 561.27\7.114 09 0 00 19.940 22)(11.172.72)184.64 (7,846.99)55 Total Current Month interest 5 0 00 (42 626.42)5.801 81 130.845 10 331,381 42 509.558.14 675.453.20 791.014.20 56 interest Accrued to Date 5 0 00 (42 626.42)(36.824 61)94.020 49 425,401.91 934.960.06 1.610.413.25 2,401.427.45 57 Balance in Account 182.323 $(5.813.029 65)(305 082.63)26,132,195 39 68.358.349.27 104.571,574.27 135.988.671.06 161.382.651.68 176,241,859 84 Note Negative amounts indicate benefit to ratepayers Exhibit No.104 Case Nos.IPC-E-02-2/ IPC-E-02-3 K.Hessing,Staff 4/22/02 Page 1 of 2 2001 -2002 TRUE-UP CALCULATIONS FOR IDAHO POWER COMPANY PCA CASE NO.IPC-E-02-2 &3 Staff CaseJurisdictionalAllocationFactor85.0%SnanngPercentage 90.0% Line No.DESCRtPT10N NOV DEC JAN FEB MAR TOTALS 1 PCA Revenue 2 Normalized Firm Load MWh 1,030,835 1,162,545 1,229,083 1.162,223 1,106.080 15,058,3633PCAComponentRatem/KWh 3 861 3.861 3.861 3.861 3.8614RevenueAllocatedat85.0%$3,383,045.84 3,815.298.31 4,033,666.04 3.814,241.55 3.629,988.65 45.802.256.05 5 LoadChange Adjustment 6 Actual Firm Load MWh 1,128,733 1,366,447 1,334,814 1,160,746 1,167,079 16.458.2057NormahzedFirmLoadMWh1,030,835 1,162.545 1,229,083 1,162.223 1.106.080 15.058.3638LoadChangeMWh97.898 203,902 105.731 (1.477)60,999 1.399.8429ExpenseAdjustment(@16.84)5 (1,648,602.32)(3.433,709.68)(1.780,510.04)24,872.68 (1,027,223.16)(24,070,027.92) 10 Non-QF PCA 11 ACTUAL 12 PurchasedWater $0 0 0 0 0 0.0013IrnpationLoadReduction$(3.577,079.98)5,162,507.08 2,343.07 0.00 0.00 89.088.478.7414frr.Reduced Revenue Adj.S (403,613.35)(840.48)840.48 0.00 0.00 (15,146,639.32)15 Astans Load reduction S 8.213,719.02 8,588.564.46 6.356,120.34 5,314,643.04 5,352,488.52 96,842,644.4216MobileGeneration$259,098.00 (14,828.54)0.00 0 00 0.00 5.491.543.1117MobileGenerationAdjustmen$0.00 0.00 0.00 0.00 0.00 (3,832,663.00)18 Master Metenng Costs $0.00 0.00 0 00 0 00 0.00 0 0019FuelExpense-Coal 5 8,034,973.56 8,226,470.98 9,870,76836 8,685,91855 8,976.729.90 106,365,8173020FuelExpense-Gas S 494.979.54 764.612.96 297,46397 286.64752 467,163,10 3.337.5531221FuelExpense-Gas Adj.$0.00 0.00 0.00 0.00 0.00 (1,101,32640)22 Non-Firm Purchases $5,628,068.27 8.014,916.80 8,387.470.97 1,279,84057 1,864,327.37 304,851,0060123QuantifedPurchasefromBPA50.00 0.00 0.00 0.00 0.00 1.148.5460024SurplusSalesS(4,375,316.84)(3,010,640.14)(8,059,153.32)(1,525,463.19)(7.368.671.88)(205,921,19108)25 FMC SecondBlock Revenue S 0.00 0.00 0.00 0.00 0.00 0.0026ExpenseAdjustment(@16.84)5 (1,648.602.32)(3,433,709.68)(1,780,510.04)24,872.68 (1,027.223.16)(24,070,027.92)27 Sub-Total 5 12,626.225.90 24,297,05344 15,075,343.83 14,066,459.17 8,264,813.85 357,053,740.98 28 K 29 Fuel Expense S 6,909.00000 7,127,000.00 6,051,000.00 5,051.000.00 4,737,000.00 66.223,0000030Non-Firm Purchases S 345,00000 844,000.00 879,000.00 642.000.00 296.000.00 11,371,0000031SurplusSalesS(3.883,00000)(2.809.000.00)(2,978,000.00)(2,781,000.00)(2,742,000.00)(27.264,00000)32 FMC SecondBlock Revenue 5 (625.63968)(739,128.10)(799.266.67)(769.197.02)(889,475.62)(9,963,51340)33 Sub-Total $2,745,360.32 4,422,871.90 3,152,733.33 2,142.802.98 1,401,524.38 40,366,48660 34 Change From Base S 9,880,865.58 19,874,181.54 11,922,61050 11,923.656.19 6,863,289.47 316,687.25438 35 Deferral (Sharedand Allocated)$7,558,862.17 15,203,748.88 9,120,79703 9,121,596.99 5,250,416.44 242,265,74960 36 QFDeferral 37 Actual (incl.Meridian Amort.)$2.396.464.10 2.540,235.92 2.649.44167 2,357,414.09 2,334,217.76 46,541,4492838Base31,539,895.00 1,713.885.00 1.567,84500 -1.459,785.00 1.314,445.00 35.428,6050039ChangeFromBaseS856,569.10 826,350.92 1,081,59667 897.629.09 1,019.772.76 11,112,84428 40 QuantifiedBenefit from BPA S (128,604.00)0.00 0.00 0.00 0.00 (33,55500) 41 Total Non-sharedDeferra!$727,965.10 826,350.92 1,081,596.67 897.629.09 1,019,772.76 11,079,28928 42 Deferral (Allocated)S 618,770.34 702.398.28 919.357.17 762,984.73 866,80685 9,417,39589 43 Mobile Home Metenng Costs 5 8,840.60 11,665.44 14,352.94 12,909.19 12,848.63 106,5288744)ntervenorFunding S 0.00 0.00 0.00 0.00 0.0029,7960345CreditFromIDACORPEnergyS(166,666.67)(166.666.67)(166,666.67)(166,666.67)(166,666.67)(1,500,00003) 46 Total Deferral 5 4.636.760.59 11.935.847.62 5,854.174.43 5.916.582.68 2,333.416.60 204,517.21431 47 Principal Balances 48 Beginning Balance 5 173.840.432.39 178.477,192.98 190,413,040.60 196,267,215.03 202,183,797.71 49 Amount Deferred S 4.636,760.59 11,935,847.62 5.854,174.43 5,916,582.68 2,333,416.60 204,517,21431 50 Ending Balance S 178,477,192.98 190,413,040.60 196,267,215.03 202,183,797.71 204.517,214.31 51 Interest Balances 52 Accrual thru Prior Month $2,401,427.45 3,278.270.98 4.079,56644 5,116.245.94 6,099,85108 53 Interest @ 6%Der Year S 869.202.16 892,385.96 952,06520 981,336.08 1,010,91899 7,142,5583254PnorMontli's laterest Adj.$7,641.36 (91,090.50)84,61430 2.269.06 204 94 (31,583.31)55 Total Current Month interest S 876.843.52 801.295.46 1.036,67950 983.605.14 1,011,12393 7,110.975.01 56 interestAccruedto Date $3,278,270.98 4,079.566.44 5,116.24594 6,099.851.08 7,110,97501 57 Balance in Account 182.323 $181,755,463.95 194,492.607.04 201,383.46097 208,283,648.78 211,628,189.31 211,628,189.31 Note:Negativeamountsindicate benef Pricing Adjustment (4,306,635.82) Balancein All Accountswith Pricing Adjustment 207,321,553.49 Exhibit No.104 Case Nos.IPC-E-02-2 IPC-E-02-3 K.Hessing,Staff 4/22/02 Page 2 of 2 ID A H O PO W E R ' S 20 0 2 PC A FO R E C A S T IP C - E - 0 2 - 2 & 3 Te n t h An n u a l PC A 14 0 , 0 0 0 , 0 0 0 12 0 , 0 0 0 , 0 0 0 10 0 , 0 0 0 , 0 0 0 PC A Ex p e n s e = NP S C + QF Ex p e n s e - FM C Se c o n d Bl o c k Re v e n u e = 68 , 0 0 9 , 3 8 5 + 47 , 5 7 4 , 3 4 4 - 9, 0 7 4 , 0 3 2 = 10 6 , 5 0 9 , 6 9 7 80 , 0 0 0 , 0 0 0 s a IP C - E - 9 5 - 5 Da t a + Re g r e s s i o n Lin e 3. 6 3 Mi l l i o n Ac r e - F e e t & A - 20 0 2 Fo r e c a s t 40 , 0 0 0 , 0 0 0 20 , 0 0 0 , 0 0 0 0 (2 0 , 0 0 0 , 0 0 0 ) 0 2, 0 0 0 , 0 0 0 4, 0 0 0 , 0 0 0 6, 0 0 0 , 0 0 0 8, 0 0 0 , 0 0 0 10 , 0 0 0 , 0 0 0 12 , 0 0 0 , 0 0 0 14 , 0 0 0 , 0 0 0 Ap r i l th r o u g h Ju l y Br o w n l e e In f l o w s (A c r e - F e e t ) HI S T O R Y OF PC A AM O U N T S 30 0 . 0 25 0 . 0 - L..O 20 0 . 0 -- C 15 0 . 0 - O --- 10 0 . 0 -- C o E 50 . 0 - 4 C)a 0. 0 - - - (S o . o ) 19 9 3 19 9 4 19 9 5 19 9 6 19 9 7 19 9 8 19 9 9 20 0 0 20 0 1 20 0 2 -P C A Am o u n t s 4. 9 14 . 7 8. 1 (1 7 . 6 ) (1 6 . 7 ) 17 . 3 (2 3 . 2 ) 14 . 8 21 7 . 0 25 3 . 8 e 2 5 PC A Ye a r on 5 oo