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Home My WebLink About20040622Schunke Direct.pdfr" r- 1"', C ,\ 'r- .t;:t:\.jcl 'It..ill L~.it.. JlJN2 1 Pl~1 2: n 3 o. .. ,. '0 ' .. ! 0 :) t. , ;. U TIL If JE S COl-'1J'iISSION BEFORE THE IDAHO PUBLIC UTiliTIES COMMISSION IN THE MATTER OF THE APPLICATION OF A VISTA CORPORATION FOR AUTHORITY TO INCREASE ITS RATES AND CHARGES FOR ELECTRIC AND NA TU RAl GAS SERVICE TO ELECTRIC AND NATURAL GAS CUSTOMERS IN THE STATE OF IDAHO. ) CASE NO. AVU-O4-) AVU-O4- DIRECT TESTIMONY OF DAVID SCHUNKE IDAHO PUBLIC UTiliTIES COMMISSION JUNE 21 , 2004 Please state your name and business address for the record. My name is David Schunke and my business address is 472 West Washington Street, Boise, Idaho. By whom are you employed and in what capaci ty? I am employed by the Idaho Public Utilities Commission as a Public Utilities Engineer. What is your educational and experience background? I received my Bachelor of Science Degree in Civil Engineering at Montana State Uni versi ty in 1972. have been licensed as a Registered Professional Engineer in Idaho since 1977.I have worked in various capaci ties, including a Cost and Materials Engineer with Morrison Knudsen Co., Inc. and a consul ting engineer wi th Stevens, Thompson & Runyan (STRAAM Engineers) As a consul tant, I worked as proj ect Engineer on numerous civil engineering proj ects in Idaho and Oregon for more than six years. Since joining the Commission Staff as a Utilities Engineer in 1979, I have been continuously involved in rate design and regulatory matters with virtually all the water , gas and electric utilities regulated by the Commission.I served as the Engineering Section Supervisor from 1983 to 1991 , Utilities Division CASE NOS. AVU-04-1/AVU-04-06/21/04 (Di)SCHUNKE, D.Staff Deputy Administrator from 1991 through 2000 and Engineer Manager from 2001 to present. INTRODUCTION AND SUMMARY What is the purpose of your testimony? The purpose of my testimony is to describe Staff's rate design proposal for electric and natural gas tariff customers. How is your testimony organized? My testimony consists of a summary of my recommendations for both electric and natural gas service followed by: (a)A general discussion of my rate design obj ecti ves for electric service. (b)An explanation of how Staff proposes to distribute the revenue requirement to the electric customer classes, and (c)Based on the resul t ing revenue requirement for the various customer classes, I then provide specific rate design proposals for each electric customer class. (d)A general discussion of my rate design obj ecti ves for natural gas serVlce. (e)An explanation of how Staff proposes to distribute the revenue requirement to the customer classes, and CASE NOS. AVU-04 -l/AVU-G- 04- 06/21/04 (Di)SCHUNKE , D.Staf f (f)Based on the resul ting revenue requirement for the various customer classes, I then provide specific rate design proposals for each natural gas customer class. Please summarlze your testimony. I am making recommendations for the electric and natural gas tariff rates.These rate proposals are based on the Staff proposed overall revenue increase in Base Rates for electric serVlce of $23 million or 15.8%, and an overall increase of $3.1 million (6.0%) for natural gas service.These rate proposals are also based on the cost of service resul ts discussed by Mr. Hessing (electric) and Mr. Fuss (natural gas) The recommended increases would move all customer classes closer to cost of service.Recommended percentage increases for each of the electric service schedules are shown in Staff Exhibi No. 143.They are as follows: Residential Service Schedule 1 -18. General Service Schedules 11 and 12 -11. Large General Service Schedules 21 and 22 -12 . Extra Large General Service Schedule 25 -20. Potlatch (Lewiston) Schedule 25 -14 . 9 Pumping Service Schedules 31 and 32 -13. Street and Area Lighting Schedules 41-49 -17. I am recommending no increase in the basic CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)S CHUNKE , Staff charge or the mlnlmum charge for Residential Schedule While I am opposed to the Company s proposal for declining blocks for Schedules 11 , 21 and 25, I am recommending that the Company s proposal be accepted for this case wi th the requirement that additional information be gathered by the next general rate case so the Company can provide a proposal to: (1 )divide Schedule 11 into two separate schedules, one demand metered and the other not demand metered (2 )eliminate the declining block rates in Schedule 11 (3 )provide a proposal to eliminate the declining block rates in Schedules 21 and 25, and (4 )implement time-of -use (TOU) rates wherever they are pract ical Changes in revenue for the natural gas servlce schedules are shown in Staff Exhibit No. 146.The percentage increases for each schedule are as follows: Residential Schedule 101 -97% Large General Service Schedule 111 -78% Large General Service High Load Factor Schedule 121 -86% Interruptible Service Schedule 131 -45% Transportation Service Schedule 146 -6 . 94 CASE NOS. AVU-04-1/AVU-04-06/21/04 (Di)SCHUNKE , D.Staff Special Contracts -0 . 0% The proposed increase for Transportation Service Schedule 146 excludes gas costs.If gas costs were included the resulting increase would be approximately 1.5%. RATE DESIGN OBJECTIVES What are Staff's rate design obj ecti ves? The utility industry and this Commission have had a long history of pricing power differently to customers with different load and usage characteristics. Residential customer rates differ from those of commercial and industrial customer rates because the cost of providing service differs depending on the characteristics of the end use.Large loads with high-load factors (constant use) tend to be less costly per kWh to serve than smaller loads with large fluctuations.Time-of -use is also a maj or factor in determining the cost of service. These differences are generally addressed by grouping customers with similar end-use characteristics together. They form a rate class such as residential , commercial pumping, industrial or light ing The cost of providing service to the varlOUS customer classes has been addressed in the cost of serVlce (COS) studies discussed by Staff wi tnesses Hessing and Fuss.The first obj ecti ve in rate design is to set rates that are more closely aligned to the cost of providing service. CASE NOS. AVU-E- 04 -l/AVU-G- 04- 06/21/04 (Di)SCHUNKE, D.Staff It is also an obj ecti ve to keep rates reasonable by balancing the cost of service goals with the goals for simplicity, for minimizing rate shock, and for promoting conservation - especially during high cost periods. The Company was not able to provide the data necessary to divide Schedule 11 and 21 into mul tiple schedules.Therefore several of my recommendations are directed at the Company s next rate filling when these issues can be more fully addressed with adequate data. CUSTOMER CLASS REVENUE ALLOCATION - ELECTRIC What cost of service study is Staff' electric rate design proposal based on? Staff wi tness Hessing has reviewed the Company s cost of service (COS) analyses, which he discusses in his testimony.This is the COS methodology that Staff believes is most appropriate and is the one Staff has based its electric rate design analysis on. Does Staff's rate design proposal strictly follow the COS results? No.Staff wi tness Hessing proposes only an incremental toward full costmove serVlce recogni t ion the fact that cost serVlce resul ts are not precise and unacceptably large lncreases some classes would occur.Staff's proposal for the revenue CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)SCHUNKE , D.Staff requirement increase for each rate class is comprised of two parts.First, 20% of the increase dictated by cost of service, is added to each class.The remainder of the necessary revenue requirement increase is spread to each rate class on a uniform percentage.These two adj ustments shown in Column 5 and 6 of Staf f Exhibi t No. 143 are added to the Current Base Revenue to arrive at the Staff- Proposed Base Revenue shown in Column 7 of Staf f Exhibi t No. 143.These are the amounts that Staff used in its rate design proposals and each class is moved 20% closer to COS. Why is the Staff proposal based on a move to cost of service of only 20%? One of my obj ecti ves in rate design is to set rates that are more closely aligned to the cost of providing service.However , it is also an obj ective to keep rates reasonable by balancing the cost of service goals with the goals for simplicity, for minimizing rate shock , and for promoting conservation.I believe that a 20% move to COS balances these objectives to achieve reasonable rates for all customer classes. In the last general rate case for Avista both the Company and Staff recommended a 1/3 move to cost of service for all customer classes.The Commission approved a 20% move the first year and an additional 15% move the CASE NOS. AVU-04-1/AVU-04-06/21/04 (Di)S CHUNKE , D .Staff following year in order to accomplish the one-third move proposed by the Company.In that order, the Commission found: Cost-of-service, however , is only one of many factors to be considered by this Commission in tariff design; Order No. 28097 at Important interests in rate stabili and continui ty preclude adopting the extremely large double digit shifts in revenues from one class to another that were requested. In addition , we recognized that the results of cost-of-service studies are not so precise that the determination of appropriate revenue shifts is an exactcertainty. Order No. 28097 at In the recent Idaho Power general rate case the Commission approved a 13.95% increase to the irrigation class, which also represented a 20% move to COS.In that order the Commission stated: we find that the revenue requirement assigned to the irrigation class shouldbe less than indicated by the cost ofservice study. The Commission has often stated that consideration such as rate stability and proportionality justify limiting the amount of the rate increase to any class of customers. Order 29505 at Staff believes that circumstances in this case also justify limiting the COS adjustment , and we believe that a 20% move to COS is reasonable.Moving the residential CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)S CHUNKE , Staff class to full COS would requlre a rate increase of 30.7%. Comparing the 20% Year 1 move to COS in the last Avista general rate case and the 20% move being proposed here, what is the magni tude of the increase proposed in this case for Residential Schedule 1 and Schedule 25 as compared to the increases in the last Avista general rate case? In the last Avista general rate case, a 20% move to COS resul ted in increases to Residential Schedule 1 and Schedule 25 of 9.5% and 10%, respectively.In this case, a 20% move to COS results in an 18.8% increase to Residential Schedule 1 and a 20% increase to Schedule 25. By further comparison , in the last Idaho Power Company general rate case, a 20% move to COS for the irrigation Schedule 24 resul ted in a 13.95% increase to irrigators. The impact of a 20% move to COS in this case considerably greater than in the two cases ci ted. Are you recommending a second step adj ustment in COS at a later time, similar to what the Commission ordered in the last rate case WWP-E- 98 -11 (Order No. 28097) ? If the Commission finds that an additional step in COS is needed, I am recommending that COS be reviewed when the PCA balance drops to zero, or at the next general rate case.If the Commission accepts the CASE NOS. AVU-04-1/AVU-04-06/21/04 (Di)S CHUNKE , Staff recommendation of Mr. Hessing to base the PCA adjustment on /kWh rather than uniform percent of revenue, that may be an appropriate time to consider an additional adjustment to COSo A general rate case is always an appropriate time to review COS. Are your rate design proposals limited to the base rates? My proposals are limited to base ratesYes. and do not address the other rate adders including, PCA rates , DSM rider, Centralia credi t or the Residential Exchange (BPA) credi t . RATE DESIGN - RESIDENTIAL What change in revenue requirement is Staff recommending for Residential Schedule Staff recommends an average overall increase In revenue of 18.8% to Residential Schedule What is your recommendation for the Residential Schedule 1 rate design? I am recommending that (1) the basic charge and minimum charge remain at $4.00;(2) the energy rate for the first 600 kWh increase by 21.9% to $0. 05554/kWh, and (3) the rate for energy use in excess of 600 kWh/month be priced 18.8% higher at $.06302/kWh. Staff Exhibi t No. 144 shows the present and proposed rates on page 2 along wi th the resul ting revenue CASE NOS. AVU-04-1/AVU-04-06/21/04 (Di)SCHUNKE, D. Staf f for Residential Schedule 1 on page 4.The proposed increase for a residential customer using an average of 941 kWh per month is $9.40 per month or a 18.8% increase in their electric bill.(The present bill for base rates without the PCA for 941 kWh is $49.41 compared to the proposed level without the PCA of $58.82. Current and proposed base rate bills are compared on Staff Exhibit No. 145. The Company has proposed an increase in the residential basic customer charge and minimum charge from $4.00 to $5.00.Do you agree wi th thi s proposal? No.The Company s proposal increases the customer basic charge and minimum charge 25%.This would have a disproportionate affect on customers with low usage.I believe the basic charge and minimum charge should remain at $4.00. Why do you believe there should be no increase in the customer basic charge and minimum charge? The customer basic charge should be based on the direct cost of meter reading and billing and should not include any fixed plant cost.I believe this is consistent with the recent Commission order in an Idaho Power rate case (Order No. 29505 at 53) "The Commission finds that a monthly service charge should recover costs that are directly attributed to the customer paying the CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)SCHUNKE, D.Staff charge.Typically, those charges are related to meter reading and customer billing. The monthly cost associated with meter reading and billing is $2.62 for this customer class. Therefore, I believe no increase can be justified. therefore believe the current rate of $4.00 is the appropriate amount for both the basic and minimum charge. RATE DESIGN SCHEDULE 11 and What change in revenue requirement is Staff recommending for General Service Schedule 11 and 12? Staff is recommending an average overall increase in revenue of 11.4% to General Service Schedule 11 and 12. The Company has proposed an addi t ional energy usage block that would provide a lower energy rate for usage In excess of 3650 kWh per month.Do you support thi s change? I am opposed to the Company s proposal for declining block for Schedules 11.However, I am recommending that the Company s proposal be accepted for this case.I recommend that prior to the next general rate case, the Company should gather sufficient data to provide a proposal to eliminate the declining block rates and divide Schedule 11 into two separate schedules, one demand metered and the other not demand metered. CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)S CHUNKE , Staf f The Company argues that the decl ining block rate is needed for Schedule 11, because under the present rates, customers whose demand exceeds 20 kW end up being billed a higher average amount per kWh than customers uslng less than 20 kW.Do you agree? It is true that the present rates effectively bi II customers, wi th demand that exceeds 20 kW , a higher amount per kWh than customers using less than 20 kW per month.However, this is true only because the Company has customers on Schedule 11 who are NOT demand-metered. Schedule 11, which has a demand charge, includes both demand-metered customers and non-demand metered customers. The non-demand metered customers, who cannot be billed for demand, are assumed to use less than 20 kW.Therefore, no customer in the class is billed for the first 20 kW of demand.The effect this has on demand-metered customers wi th higher usage is that they tend to pay more per kWh. Do you believe there is a better more direct solution to this problem than creating declining block rates? Two separate schedules should beYes. created. One for the demand metered customers and one for the non-demand metered customers.Having both demand- metered and non-demand metered customers on a demand schedule is the real problem.The Company fix to not bill CASE NOS. AVU-04-1/AVU-04-06/21/04 (Di)S CHUNKE , Staff the first 20 kW of demand only created a new problem which is higher use customers paying effectively more per kWh. The Company s proposed fix for this is a declining block ra te I believe the real fix is to create two separate schedules. Unfortunately the Company does not have sufficient data at this time to separate the schedule between demand and non-demand metered customers. Therefore, I am recommending that the Company s proposal for a declining block be accepted until the data can be made available to properly separate the schedule.The Company should be directed to collect the necessary customer data and the rate class should be separated as a part of the next general rate case. What rates are you recommending for General Service Schedule 11 and 12? I am recommending no change in the basic charge the minimum charge or the demand charge.The energy rate for the first 3650 kWh per month should be 7. 527 /kWh and for usage above 3650 kWh per month should be 6.3 98 /kWh. Staff Exhibi t No. 144, page 2 , shows the present and Staff -proposed rates along with the resulting revenue on page 4 for Schedule 11 and 12. RATE DESIGN LARGE GENERAL SERVICE SCHEDULE 21 and What is the overall rate change recommended CASE NOS. AVU-04-1/AVU-04-06/21/04 (Di)SCHUNKE, D. Staf f by Staff for the Large General Service Schedule 21 and 22? Staff recommends an overall revenue increase of 12.9%. What is your recommendation for the Large General Service Schedule 21 and 22 rate design? I am recommending that the Company s proposal for the second block energy rate and the increases to the demand charges be accepted.The first block demand charge would increase from $225 to $250 and the second block demand charge would increase from $2.75 to $3.00.The first block energy rate would be 4.664 ~/kWh and the second block would be 3. 964 /kWh.These rates are shown on Staff Exhibi t No. 144, page I also recommend that the Company develop additional information before the next rate case assessing the economical impact of the second block to justify continual use of a declining block energy charge. RATE DESIGN EXTRA LARGE GENERAL SERVICE SCHEDULE What is Staff's recommended change in the revenue requirement for Extra Large General Service Schedule 25 (including Potlatch)? Staff recommends an overall revenue increase of 20% for Extra Large General Service 25, with Potlatch recel vlng a 14.9% increase. What is your recommendation for Schedule CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)S CHUNKE , Staff rate design? I am recommending that the Company s proposal for the second block energy rate and the increases in the demand charges be accepted.The first block demand charge would increase from $7,500 to $9,000 and the second block demand charge would increase from $2.25 to $2.75. The first block energy rate would be 3. 873 ~/kWh and the second block would be 3.26 8 /kWh.These rates are shown on Staff Exhibit No. 144, page The Company shoul d be prepared to demonstrate that the Schedule 21 and 22 tail blocked rates exceed the Company s variable costs and provide a small contribution to the Company s fixed costs. RATE DESIGN IRRIGATION SCHEDULE 31 What is Staff's recommended revenue requirement increase for Pumping Schedule 31? Staff recommends that Schedule 31 rates be increased by 13. 5 % . What is your rate design proposal for Schedule 31? I accept the Company s recommendation that all of the proposed increase for Schedule 31 be appl ied to the energy rate.The first block energy rate would be 6 .295 /kWh and the second block energy rate would be 5 . 3 51 ~ / kWh.The basic charge would remain at $6.00. These rates are shown on Staff Exhibit No. 144, page CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)SCHUNKE , D.Staff RATE DESIGN STREET AND AREA LIGHTS SCHEDULES 41- 4 9 What is Staff's recommended revenue requirement increase for Street and area lights Schedule 41-49? Staff recommends that revenue for Schedules 41-49 be increased by 13.5%. What is your rate design proposal for Street and Area Lights Schedules 41-49? I am recommending a uniform increase in all the Schedule 41-49 tariff rates to accomplish the 17. lncrease In revenue. NATURAL GAS GENERAL How did Staff calculate the revenue allocation between the natural gas customer classes? Staff balanced the obj ecti ve to move each class closer to cost of service wi th the obj ecti ve of achieving an equal contribution to the non-gas related costs (which is referred to the margin) from Schedules 121, 131 , and 146.Staff's proposed revenue allocation between classes was achieved by starting wi th the cost of servlce resul ts provided by Mr. Fuss.Then Schedules 121 131 and 146 were moved closer to an equal contribution to the margin. What cost of serVlce study is Staff's rate design proposal based on? CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)S CHUNKE , Staff Staff witness Fuss has completed a review of the Company s gas cost of service (COS) analyses and has made a number of adj ustments, which he discusses in his testimony.This is the cost of service methodology that Staff believes is most appropriate and is the one Staff has based its natural gas rate design analysis on. Why is it important to equalize the contribution to the non-gas related costs (margin) for Schedules 121 , 131 , and 146? In order to discourage switching between schedules and to protect against a revenue shortfall for the Company the margin for each of these schedules should be fairly close.The difference in the margin in Staff' proposal is equal to the difference in the Company s rate proposal. The Final Revenue allocation is shown in Column '' of Staff Exhibit No 146.This is the amount that Staff used in its rate design proposals.Present and proposed rates for all the natural gas schedules are summarized in Staff Exhibit No. 147 , pages 2, 3 and 4 and again on Staff Exhibit No. 148. GENERAL SERVICE SCHEDULE 101 What change in revenue requirement is Staff recommending for Residential Schedule 101? Staff recommends an average overall increase CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)SCHUNKE , D.Staff In revenue of 6.97% to Residential Schedule 101. What is your recommendation for the Residential Schedule 101 rate design? I am recommending that (1) the basic charge and the minimum charge remain at $ 3 .28, and (2) the energy ra te be increased to 79. 678 ~ / therm. Staff Exhibit No. 147 shows the existing and proposed rates along with the resulting revenue for Residential Schedule 101. The Company has proposed an increase in the residential basic charge and the minimum charge from $3. to $ 5 . 00 .Why are you proposing no increase in these charge s The Company Exhibi t No.2 3, page 4, shows that the cost of meter reading and billing for Schedule 101 is $2.46.These are the costs that I believe are appropriately recovered in the basic charge.This is consistent with the recent Commission order in an Idaho Power rate case (Order No. 29505, page 53) "The Commission finds that a monthly service charge should recover costs that are directly attributed to the customer paying the charge.Typically, those charges are related to meter reading and customer billing. LARGE GENERAL SERVICE SCHEDULE 111 What change in revenue requirement is Staff CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)SCHUNKE, D.Staff recommending for Large General Service Schedule 111? Staff recommends an average overall increase In revenue of 2. 78% to Schedule 111. What is your recommendation for the Schedule 111 rate design? I am recommending that the energy rate be increased to 78. 190 /therm in the first block , 76.379 /therm in the second block and 66 .182 /therm in the third block. LARGE GENERAL SERVICE-HIGH LOAD FACTOR SCHEDULE 121 What change in revenue requirement is Staff recommending for Large General Service-High Load Factor Schedule 121? Staff recommends an average overall increase In revenue of 1.86% to Schedule 121. What is your recommendation for the Large General Service-High Load Factor Schedule 121 rate design? I am recommending that the energy rate be increased to 77 .103 ~/therm in the first block, 76.379 /therm in the second block and 66 .182 /therm in the third block and 64. 313 ~/therm in the fourth and final block. INTERRUPTIBLE SERVICE SCHEDULE 131 What change in revenue requirement is Staff recommending for Interruptible Service Schedule 131? CASE NOS. AVU-04-1/AVU-04- 06/21/04 (Di)SCHUNKE , D.Staff Staff recommends an average overall increase In revenue of 1.45% to Interruptible Service Schedule 131. What is your recommendation for the Ihterruptible Service Schedule 131 rate design? I am recommending that the energy rate be increased to 56. 5 31 ~ / therm. TRANSPORTATION SERVICE SCHEDULE 146 What change in revenue requirement is Staff recommending for Transportation Service Schedule 146? Staff recommends an average overall increase In revenue of 6.94% to Transportation Service Schedule 146. What is your recommendation for the Transportation Service Schedule 146 rate design? I am recommending that the Company-proposed basic charge of $200/month be approved and the energy rate be increased to 10. 908 ~ / therm. Does this conclude your direct testimony in this proceeding? Yes, it does. CASE NOS. AVU-04-1/AVU-04-06/21/04 (Di)SCHUNKE , D.Staff Li n e Ty p e o f S e r v i c e (1 ) Ra t e Sc h . No . St a f f C a s e Av i s t a U t i l i t i e s - E l e c t r i c St a t e o f I d a h o 20 % C o s t o f S e r v i c e No r m a l i z e d 1 2 - Mo n t h s E n d i n g D e c e m b e r 3 1 , 2 0 0 2 (2 ) Av e r a g e Nu m b e r o f Cu s t o m e r s (3 ) Sa l e s No r m a l i z e d (M W h l (4 ) (6 ) (5 ) (6 ) 20 % c a s Un i f o r m % o n ca s R e v e n u e Re v e n u e Cu r r e n t R e v . 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 (7 ) St a f f Pr o p o s e d Re v e n u e (8 ) Av e r a g e Ra t e rt / k W h Pe r c e n t Ch a n Q e (9 ) (1 0 ) (1 1 ) Cu r r e n t Re v e n u e ca s In d e x % m o v e to c a s Re s i d e n t i a l 87 , 4 9 4 98 8 38 0 64 8 , 00 0 15 7 33 3 23 1 , 4 6 7 64 6 , 55 5 52 6 , 02 1 18 . 90 . 20 % Ge n e r a l S e r v i c e 05 1 22 5 32 8 16 , 21 2 00 0 00 4 89 9 ) (2 0 0 98 0 ) 04 6 68 6 05 7 70 7 11 . 4 % 11 8 . 20 % La r g e G e n e r a l S e r v i c e 78 9 67 4 , 17 7 80 4 00 0 39 4 72 8 78 , 94 6 39 3 , 83 6 39 , 27 6 , 78 2 12 . 11 1 . 20 % Ex t r a L a r g e G e n e r a l S e r v i c e 30 3 , 70 7 10 , 4 7 5 , 00 0 88 7 96 9 77 7 , 59 4 32 2 , 4 1 8 57 5 , 01 2 20 . 87 . 20 % Po t l a t c h 87 0 08 6 69 6 , 00 0 10 0 07 3 62 0 01 5 3, 4 9 6 , 4 8 6 81 2 50 0 14 . 10 3 . 20 % Pu m p i n g S e r v i c e 04 3 48 , 92 2 54 9 , 00 0 11 6 , 63 7 23 , 32 7 32 1 79 9 89 4 12 6 13 . 10 8 . 20 % St r e e t a n d A r e a L i g h t s 41 - 98 3 86 4 00 0 42 7 03 5 85 , 4 0 7 23 5 32 1 18 4 72 8 16 . 17 . 95 . 4 % 20 % To t a l / A v e r a g e 12 3 58 3 14 6 , 24 8 00 0 07 8 , 87 6 61 5 , 77 5 18 , 4 6 3 , 10 1 16 9 , 32 6 87 6 5. 4 2 15 . 10 0 . * E x c l u d e s a l l a d j u s t m e n t s t o b a s e r a t e s . ~d Ot I 1 N ' Po ' X .. . . . r : / J r : J ) . :: r ' -- - ( : ) ( 1 ) ,.. . . . :: r ' g" . ~ o ..- t - . z Jr ~ ~ ~ r: / J ~ ~ .. . . . ..- t - e e ~ Po ' I I V J ~C 1 t I 1 -' ~ AV I S T A U T I L I T I E S PR O F O R M A E L E C T R I C R E V E N U E U N D E R P R E S E N T P R O P O S E D R A T E S ST A F F P R O P O S A L ST A T E O F I D A H O YE A R E N D E D 1 2 / 3 1 / 0 2 WK P A P E R RE S I D E N T I A L GE N E R A L S V C LG . G E N . S V C EX L G G E N PU M P I N G S& A L T G RE F E R E N C E TO T A L SC H E D U L E 1 SC H 1 1 & 1 2 SC H 2 1 & 2 2 SC H 2 5 PO T L A T C H SC H 3 1 SC H 4 1 - 4 9 PR E S E N T B I L L D E T E R M I N A N T S KI L O W A T T H O U R S ( K W H S ) ED 1 BL O C K 1 62 5 08 1 57 8 52 9 , 64 8 14 7 23 0 12 8 , 4 5 2 67 0 , 09 1 98 0 30 3 , 70 7 , 4 8 1 87 0 08 5 , 62 0 21 , 4 1 9 89 8 ED 1 BL O C K 2 48 5 42 8 , 24 4 45 7 53 0 57 8 89 7 66 6 ED 1 BL O C K 3 ED 1 0 - ST R E E T & A R E A L I G H T S 98 3 00 5 98 3 00 5 SU B T O T A L 12 3 , 4 9 2 82 7 98 7 17 8 72 5 23 0 , 12 8 45 2 67 0 , 09 1 , 98 0 30 3 70 7 , 4 8 1 87 0 08 5 , 62 0 31 7 56 4 98 3 00 5 EE 1 NE T S H I F T I N G A D J U S T M E N T 86 8 69 4 86 8 69 4 SU B T O T A L 12 3 , 4 9 2 82 7 98 7 17 8 , 72 5 22 6 25 9 75 8 67 3 96 0 67 4 30 3 , 70 7 , 4 8 1 87 0 08 5 , 62 0 31 7 56 4 98 3 , 00 5 ED 1 AD J U S T M E N T T O A C T U A L 93 5 24 5 73 2 51 2 TO T A L B E F O R E A D J U S T M E N T 13 0 , 4 2 8 , 07 2 99 4 62 6 , 4 5 7 22 6 25 9 75 8 67 3 96 0 67 4 30 3 70 7 , 4 8 1 87 0 , 08 5 62 0 80 5 07 7 98 3 00 5 EA 3 WE A T H E R & U N B I L L E D A D J . K W H S 84 5 08 9 24 6 90 6 93 1 26 1 21 6 57 3 11 6 50 5 TO T A L P R O F O R M A K W H S 12 3 , 58 2 98 3 98 8 , 37 9 , 55 1 22 5 32 8 , 4 9 7 67 4 17 7 24 7 30 3 70 7 , 4 8 1 87 0 , 08 5 , 62 0 92 1 58 2 98 3 00 5 ED 1 TO T A L B I L L S 04 9 , 93 1 19 2 60 7 21 , 4 6 6 16 8 51 0 ED 1 MI N I M U M B I L L S ED 1 EX C E S S D E M A N D 38 2 09 9 , 4 9 0 28 5 , 4 9 3 27 1 84 2 PR O P O S E D B I L L D E T E R M I N A N T S KI L O W A T T H O U R S ( K W H S ) ED 1 , ED 8 - , B L O C K 1 46 5 , 4 1 0 , 02 6 52 9 64 8 14 7 19 8 , 4 8 5 , 57 3 62 5 85 6 , 4 0 8 00 0 00 0 00 0 , 00 0 21 , 4 1 9 89 8 ED 1 5 BL O C K 2 67 2 , 4 6 0 , 4 2 6 45 7 53 0 57 8 84 9 , 86 1 38 9 22 0 21 9 , 70 7 , 4 8 1 86 4 08 5 , 62 0 89 7 66 6 BL O C K 3 ST R E E T & A R E A L I G H T S 98 3 00 5 98 3 , 00 5 SU B T O T A L 15 0 85 3 , 4 5 7 98 7 17 8 , 72 5 23 0 33 5 , 4 3 4 69 7 24 5 , 62 8 30 3 70 7 48 1 87 0 08 5 62 0 31 7 56 4 98 3 00 5 NE T S H I F T I N G A D J U S T M E N T 86 8 69 4 86 8 69 4 SU B T O T A L 15 0 85 3 , 4 5 7 98 7 17 8 , 72 5 22 6 46 6 74 0 70 1 11 4 32 2 30 3 70 7 , 4 8 1 87 0 , 08 5 , 62 0 31 7 56 4 98 3 00 5 AD J U S T M E N T T O A C T U A L 38 5 73 2 20 6 98 2 15 3 64 8 51 2 TO T A L B E F O R E A D J U S T M E N T 13 0 42 8 07 2 99 4 62 6 , 4 5 7 22 6 , 25 9 , 75 8 67 3 , 96 0 , 67 4 30 3 70 7 , 4 8 1 87 0 , 08 5 62 0 48 , 80 5 , 07 7 98 3 00 5 WE A T H E R & U N B I L L E D A D J . K W H S 84 5 08 9 24 6 90 6 93 1 26 1 21 6 57 3 11 6 50 5 TO T A L P R O F O R M A K W H S 12 3 58 2 98 3 98 8 37 9 55 1 22 5 , 32 8 , 4 9 7 67 4 17 7 24 7 30 3 70 7 , 4 8 1 87 0 08 5 62 0 92 1 58 2 98 3 , 00 5 TO T A L B I L L S 04 9 , 93 1 19 2 60 7 46 6 16 8 51 0 MI N I M U M B I L L S Ex h i b i t N o . 1 4 4 EX C E S S D E M A N D Ca s e N o . A V U - 04 - 76 , 38 2 09 9 , 4 9 0 28 5 49 3 27 1 84 2 A V U - 04 - Hi r s c h k o r n W o r k p a p e r s D. S c h u n k e , S t a f f 6/ 2 1 / 0 4 Pa g e 1 o f 4 Pa g e EA 1 - 5 r e v . m o d e l WK P A P E R RE F E R E N C E PR E S E N T R A T E S BA S I C C H A R G E MO N T H L Y M I N I M U M BL O C K 1 P E R K W H BL O C K 2 P E R K W H BL O C K 3 P E R K W H AD J U S T T O A C T U A L P E R K W H DE M A N D B L O C K 1 DE M A N D B L O C K 2 PR O P O S E D R A T E S EC 1 BA S I C C H A R G E EC 1 MO N T H L Y M I N I M U M EC 1 BL O C K 1 P E R K W H EC 1 BL O C K 2 P E R K W H EC 1 BL O C K 3 P E R K W H Di f f e r e n c e b e t w e e n B l k 1 a n d B l k 2 AD J U S T T O A C T U A L P E R K W H EC 1 DE M A N D B L O C K 1 EC 1 DE M A N D B L O C K 2 AV I S T A U T I L I T I E S PR O F O R M A E L E C T R I C R E V E N U E U N D E R P R E S E N T P R O P O S E D R A T E S ST A T E O F I D A H O YE A R E N D E D 1 2 / 3 1 / 0 2 TO T A L RE S I D E N T I A L SC H E D U L E 1 GE N E R A L S V C SC H 1 1 & 1 2 LG . G E N . S V C SC H 2 1 & 2 2 EX L G G E N SC H 2 5 PU M P I N G SC H 3 1 PO T L A T C H $4 . $6 . $6 . S& A L T G SC H 4 1 - 55 5 ~ 30 3 ~ 56 4 ~ 99 6 ~ 87 4 ~ 87 4 ~ 71 6 ~ 54 8 ~ de l t a 11 6 . 42 % 32 7 ~ 79 . 57 % 21 O ~ 7 . 19 2 ~ 16 3 ~ 3. 4 4 9 ~ 18 3 ~ $3 . $2 2 5 . $2 . 50 0 . $2 . 2 5 50 0 . $2 . 0' \ t : ; j tr : 1 N' ~ ~ ,. . . . . . r : / ) . r J l :: r -- - - (1 ) ... . . . ~: : r Zg : ' . ~ Z ;, o ~ ~ ~ ~ (J q ~~ ~ , . . . . . . (1 ) . - + - c : : : c: : : +: : . N ~ +: : . 0 ~ Cl tr : 1 +: : . +: : . I ,. . . . . . ,. . . . . . - - - - $4 . $6 . $6 . 55 4 ~ 52 7 ~ 66 4 ~ 87 3 ~ 87 3 ~ 29 5 ~ 30 2 ~ 39 8 ~ 96 4 ~ 26 8 ~ 26 8 ~ 35 1 ~ 11 3 . 47 % 85 . 00 % 85 . 00 % 84 . 38 % 84 . 38 % 85 . 00 % 32 7 ~ 01 2 ~ 82 6 ~ 14 1 ~ 65 6 ~ 91 5 ~ $2 5 0 . 00 0 . $9 , 00 0 . $3 . $3 . $2 . $2 . 87 8 , 02 1 87 8 02 2 Pa g e 2 Hi r s c h k o r n W o r k p a p e r s EA 1 - 5 r e v , m o d e l AV I S T A U T I L I T I E S PR O F O R M A E L E C T R I C R E V E N U E U N D E R P R E S E N T P R O P O S E D R A T E S ST A T E O F I D A H O YE A R E N D E D 1 2 / 3 1 / 0 2 WK P A P E R RE S I D E N T I A L GE N E R A L S V C LG . G E N . S V C EX L G G E N PU M P I N G S& A L T G RE F E R E N C E TO T A L SC H E D U L E 1 SC H 1 1 & 1 2 SC H 2 1 & 2 2 SC H 2 5 PO T L A T C H SC H 3 1 SC H 4 1 - PR E S E N T R E V E N U E BI L L I N G R E V E N U E BA S I C C H A R G E $5 , 4 3 0 , 4 2 6 19 9 72 4 15 5 64 2 $7 5 , 06 0 MO N H T L Y M I N I M U M BL O C K 1 $1 0 0 96 7 15 5 $2 4 12 5 , 4 7 3 $1 5 10 5 , 63 2 $2 6 77 6 , 87 6 72 8 55 3 $2 5 00 6 26 1 22 4 36 1 BL O C K 2 $2 5 , 53 1 63 2 $2 4 26 2 84 7 26 8 78 6 BL O C K 3 DE M A N D B L O C K 1 17 9 85 0 82 9 85 0 26 0 00 0 $9 0 00 0 DE M A N D B L O C K 2 79 4 93 8 $2 6 7 33 7 02 3 59 8 $6 4 2 35 9 86 1 64 5 ED 6 - PO W E R F A C T O R A D J U S T M E N T $3 5 , 53 8 $4 5 9 $3 4 05 2 02 8 ED 1 5 EF 1 PR I M A R Y V O L T A G E D I S C O U N T ($ 4 4 7 22 8 ) ($ 2 9 85 0 ) ($ 1 5 5 81 0 ) ($ 2 6 1 56 8 ) AN N U A L M I N I M U M A D J U S T M E N T EG 1 ST R E E T & A R E A L I G H T R E V E N U E 86 4 12 8 86 4 12 8 SU B T O T A L $1 4 6 , 35 6 , 4 4 0 $5 2 58 8 04 4 $1 6 , 52 9 06 9 $3 4 63 4 52 5 $1 0 , 4 7 5 10 2 $2 7 69 6 , 33 7 56 9 23 5 86 4 12 8 EE 1 NE T S H I F T I N G A D J U S T M E N T 25 6 25 6 29 4 16 1 03 8 SU B T O T A L $1 4 6 26 1 18 4 $5 2 58 8 , 04 4 $1 6 27 2 77 5 $3 4 79 5 , 56 3 $1 0 , 4 7 5 10 2 $2 7 69 6 , 33 7 56 9 23 5 86 4 12 8 AD J U S T T O A C T U A L $3 7 0 , 05 0 $3 9 6 74 8 ($ 2 6 69 8 ) TO T A L B I L L I N G R E V E N U E $1 4 6 63 1 23 4 $5 2 98 4 79 2 $1 6 27 2 77 5 $3 4 79 5 56 3 $1 0 , 47 5 10 2 $2 7 69 6 , 33 7 54 2 53 6 86 4 12 8 AD J U S T M E N T R E V E N U E UN B I L L E D R E V E N U E A D J U S T M E N T EI 1 BA S E L O A D K W H S 27 5 65 5 74 5 67 2 19 1 81 7 22 1 66 1 11 6 50 5 EA 5 BA S E L O A D R A T E 62 4 56 4 99 6 21 0 BA S E L O A D R E V E N U E $6 2 00 0 $3 4 , 4 8 2 $1 2 59 1 85 8 ' 06 9 EI 1 WE A T H E R - SE N S I T I V E K W H S 79 4 63 4 96 8 02 3 82 0 93 2 67 9 EA 5 WE A T H E R - SE N S I T I V E R A T E 30 3 56 4 99 6 WE A T H E R - SE N S I T I V E R E V E N U E ($ 3 7 0 , 59 7 ) ($ 3 1 6 , 4 8 4 ) ($ 5 3 88 6 ) ($ 2 2 7 ) TO T A L U N B I L L E D K W H A D J U S T 51 8 , 97 9 22 2 35 1 62 9 11 5 21 5 98 2 11 6 , 50 5 TO T A L U N B I L L E D R E V E N U E A D J ($ 3 0 8 59 7 ) ($ 2 8 2 00 2 ) ($ 4 1 29 5 ) $8 , 63 1 06 9 WE A T H E R N O R M A L I Z A T I O N A D J EH 1 WE A T H E R - SE N S I T I V E K W H S 32 6 11 0 02 4 55 5 30 2 14 6 59 1 EA 5 WE A T H E R - SE N S I T I V E R A T E 30 3 56 4 99 6 WE A T H E R - SE N S I T I V E R E V E N U E ($ 7 4 14 1 ) ($ 5 4 33 2 ) ($ 1 9 , 83 3 ) $2 4 OT H E R A D J U S T M E N T S TO T A L A D J U S T M E N T R E V E N U E ($ 3 8 2 73 8 ) ($ 3 3 6 33 4 ) ($ 6 1 12 8 ) $8 , 65 4 $6 , 06 9 TO T A L B I L L I N G R E V E N U E 14 6 63 1 23 4 98 4 79 2 27 2 77 5 79 5 56 3 10 2 69 6 33 7 54 2 53 6 86 4 12 8 TO T A L P R E S E N T R E V E N U E Ex h i b i t N o . 1 4 4 $ 1 4 6 , 24 8 49 6 $5 2 64 8 , 4 5 8 $1 6 21 1 64 7 $3 4 80 4 21 7 $1 0 , 47 5 10 2 $2 7 69 6 , 33 7 $2 , 54 8 , 60 6 86 4 12 8 Ca s e N o . A V U - 04 - A V U - 04 - Hi r s c h k o r n W o r k p a p e r s D, S c h u n k e , S t a f f Pa g e 3 EA 1 - 5 r e v . m o d e l 6/ 2 1 / 0 4 Pa g e 3 o f 4 AV I S T A U T I L I T I E S PR O F O R M A E L E C T R I C R E V E N U E U N D E R P R E S E N T P R O P O S E D R A T E S ST A T E O F I D A H O YE A R E N D E D 1 2 / 3 1 / 0 2 WK P A P E R RE S I D E N T I A L GE N E R A L S V C LG . G E N . S V C EX L G G E N PU M P I N G S& A L T G RE F E R E N C E TO T A L SC H E D U L E 1 SC H 1 1 & 1 2 SC H 2 1 & 2 2 SC H 2 5 PO T L A T C H SC H 3 1 SC H 4 1 - PR O P O S E D R E V E N U E BI L L I N G R E V E N U E BA S I C C H A R G E $5 , 4 3 0 , 4 2 6 19 9 , 72 4 15 5 64 2 $7 5 06 0 MO N H T L Y M I N I M U M BL O C K 1 $7 8 38 0 , 97 4 $2 9 , 4 1 8 86 0 $1 4 93 9 25 1 $2 9 , 18 8 , 70 5 $3 , 25 3 43 7 $2 3 2 36 2 34 8 35 9 BL O C K 2 $7 0 61 2 71 5 $2 8 , 83 5 , 4 7 9 03 7 63 5 83 0 03 4 18 0 , 38 1 $2 8 , 23 6 , 4 7 8 49 2 70 8 BL O C K 3 DE M A N D B L O C K 1 $6 , 98 6 50 0 36 6 50 0 $1 , 51 2 00 0 $1 0 8 , 00 0 DE M A N D B L O C K 2 84 8 , 4 7 8 $2 6 7 33 7 $3 , 29 8 , 4 7 0 $7 8 5 10 6 $3 , 4 9 7 56 6 PO W E R F A C T O R A D J U S T M E N T $3 5 , 53 8 $4 5 9 $3 4 05 2 02 8 PR I M A R Y V O L T A G E D I S C O U N T ($ 4 4 7 22 8 ) ($ 2 9 85 0 ) ($ 1 5 5 81 0 ) ($ 2 6 1 56 8 ) AN N U A L M I N I M U M A D J U S T M E N T EG 1 ST R E E T & A R E A L I G H T R E V E N U E 18 4 85 6 18 4 85 6 SU B T O T A L $1 7 1 03 2 25 9 $6 2 , 4 5 4 06 3 $1 8 , 4 0 0 32 4 $4 0 68 7 91 1 $1 2 57 5 , 11 4 $3 1 , 81 2 83 7 $2 , 91 7 15 4 18 4 85 6 NE T S H I F T I N G A D J U S T M E N T 25 6 25 6 29 4 16 1 03 8 SU B T O T A L $1 7 0 93 7 00 3 $6 2 45 4 06 3 $1 8 , 14 4 03 0 $4 0 84 8 94 9 $1 2 57 5 11 4 $3 1 81 2 83 7 91 7 15 4 18 4 85 6 AD J U S T T O A C T U A L 15 7 76 5 47 1 18 2 58 3 58 2 05 0 31 4 TO T A L B I L L I N G R E V E N U E $1 6 9 77 9 , 23 9 $6 2 92 5 24 6 $1 8 , 12 7 44 7 $3 9 26 6 89 9 $1 2 57 5 11 4 $3 1 81 2 83 7 88 6 , 84 0 18 4 85 6 AD J U S T M E N T R E V E N U E UN B I L L E D R E V E N U E A D J U S T M E N T 0' \ ~ tr j B A S E L O A D K W H S 27 5 , 65 5 74 5 , 67 2 19 1 81 7 22 1 66 1 11 6 50 5 N . ~ & B A S E LO A D R A T E 62 4 52 7 66 4 87 3 91 5 "" " ' " ' e n go (" t ) 0 - : B A S E L O A D R E V E N U E $7 3 60 1 $4 1 93 5 $1 4 , 4 3 7 $1 0 , 33 8 89 1 ~ S :: + . W E A T H E R - SE N S I T I V E K W H S 79 4 63 4 96 8 02 3 82 0 93 2 67 9 ~. . . . ~ ~ ~ W E A T H E R - SE N S I T I V E R A T E 30 2 52 7 66 4 cf J ~ 2 ~ "" " ' " ' W E A T H E R - SE N S I T I V E R E V E N U E ($ 4 3 8 , 18 3 ) ($ 3 7 6 , 13 0 ) ($ 6 1 , 78 8 ) ($ 2 6 5 ) S- I ~ t T O T A L UN B I L L E D K W H A D J U S T 51 8 97 9 22 2 35 1 62 9 , 11 5 21 5 98 2 11 6 50 5 0 ~ 0 t; I 1 T O T A L U N B I L L E D RE V E N U E A D J ($ 3 6 4 58 2 ) ($ 3 3 4 19 5 ) ($ 4 7 35 1 ) $1 0 07 3 $6 , 89 1 ~ ~ WE A T H E R N O R M A L I Z A T I O N A D J .! . . . . . ~ W E A T H E R - SE N S I T I V E K W H S 32 6 , 11 0 02 4 55 5 30 2 14 6 59 1 WE A T H E R - SE N S I T I V E R A T E 30 2 52 7 66 4 WE A T H E R - SE N S I T I V E R E V E N U E ($ 8 7 , 28 6 ) ($ 6 4 57 2 ) ($ 2 2 , 74 1 ) $2 8 OT H E R A D J U S T M E N T S TO T A L A D J U S T M E N T R E V E N U E ($ 4 5 1 86 7 ) ($ 3 9 8 76 7 ) ($ 7 0 09 2 ) $1 0 , 10 1 89 1 TO T A L B I L L I N G R E V E N U E $1 6 9 . 77 9 . 23 9 $6 2 . 92 5 . 24 6 $1 8 . 12 7 . 4 4 7 $3 9 . 26 6 . 89 9 $1 2 . 57 5 . 11 4 $3 1 . 81 2 . 83 7 $2 . 88 6 . 84 0 $2 . 18 4 . 85 6 TO T A L P R O P O S E D R E V E N U E $1 6 9 , 32 7 , 37 2 $6 2 52 6 , 4 7 9 $1 8 05 7 , 35 4 $3 9 , 27 6 , 99 9 $1 2 57 5 , 11 4 $3 1 81 2 83 7 89 3 73 2 18 4 85 6 TO T A L P R E S E N T R E V E N U E 14 6 64 8 21 1 64 7 80 4 21 7 10 2 69 6 33 7 54 8 60 6 86 4 12 8 EL 1 TO T A L R E V E N U E I N C R E A S E $2 3 , 07 8 , 87 6 $9 , 87 8 , 02 1 $1 , 84 5 , 70 7 $4 , 47 2 , 78 2 $2 , 10 0 , 01 2 11 6 , 50 0 $3 4 5 , 12 6 $3 2 0 , 72 8 PE R C E N T R E V E N U E I N C R E A S E 15 . 78 % 18 . 76 % 11 . 39 % 12 , 85 % 20 . 05 % 14 . 86 % 13 . 54 % 17 . 21 % Hi r s c h k o r n W o r k p a p e r s Pa g e 4 EA 1 - 5 r e v , m o d e l ~t ) nt I j N' ~ ~ C/ ) e n :: r --- - (1 ) ... . . 1? : : r Z sr . +- " ~ 0 '-+ :: s . Z ~ ~ ~ ~ ~~ ~ ~ .- + ee ~ v- . ~a t I j ~ ~ ~ ~ 35 0 30 0 25 0 UJ . 20 0 .& : : 15 0 10 0 1 b i l l + Av i s t a E l e c t r i c R e s i d e n t i a l R a t e C o m p a r i s o n -- - Cu r r e n t r a t e -+ - P r o p o s e d ra t e Co s U K W H / # # # Us a g e K W H Pa g e 06 8 06 6 .& : : UJ . 06 4 c: ( 06 2 05 8 AV I S T A U T I L I T I E S ST A F F P R O P O S E D R E V E N U E I N C R E A S E B Y S C H E D U L E ID A H O - G A S 12 M O N T H S E N D E D D E C E M B E R 3 1 20 0 2 (O O O s o f D o l l a r s ) Li n e Sc h e d u l e Re v e n u e U n d e r Pr o p o s e d Re v e n u e U n d e r Th e r m s Re v e n u e I n c r e a s e Pe r c e n t Co m p a n y Ty p e o f S e r v i c e Nu m b e r Pr e s e n t R a t e s ( 1 ) In c r e a s e Pr o p o s e d R a t e s ( 1 ) (O O O s ) Pe r T h e r m In c r e a s e CO S In d e x In c r e a s e (a ) (b ) (c ) (d ) (e ) (f ) (g ) (h ) (I ) 1 G e n e r a l S e r v i c e 10 1 $4 0 11 4 79 4 $4 2 90 8 50 9 7 8 5.4 8 1 97 % 99 . 50 % 10 . 2 L a r g e G e n e r a l S e r v i c e 11 1 $8 , 95 5 $2 4 9 $9 , 20 3 12 9 3 0 92 3 c t 78 % 10 1 . 16 % 3 H i g h A n n u a l L o a d F a c t o r L G S 12 1 52 2 $2 8 55 0 23 5 7 19 9 c t 86 % 10 1 . 4 3 % 4 I n t e r r u p t i b l e S e r v i c e 13 1 $3 8 5 $3 9 1 69 1 80 7 c t 1. 4 5 % 10 2 . 83 % 3. 4 % 5 T r a n s p o r t a t i o n S e r v i c e 14 6 $4 4 4 $3 1 $4 7 5 42 0 0 73 4 c t 94 % 11 9 . 02 % 18 . 6 S p e c i a l C o n t r a c t s $5 0 0 $5 0 0 58 8 5 2 OO O c t 00 % 10 0 . 00 % 7 T o t a l $5 1 91 9 $3 , 10 7 $5 5 , 02 7 13 0 0 0 7 39 0 c t 98 % 10 0 . 00 % (1 ) I n c l u d e s P u r c h a s e A d j u s t m e n t S c h e d u l e 1 5 0 Ex c l u d e s o t h e r r a t e a d j u s t m e n t s ~t j nt I 1 tV . PJ ~ .. . . . . . ( / ) r : n :: r ... . . . . . . . ,.. . . . . ~~ Zg ' . :: : : 1 ~ Z ~ ~ ~ ~ ~~ ~ . . . . . . . .- + ~~ . J : : : . PJ I 0'\ ~C ) t I 1 .J : : : . .J : : : . ... . . . . ! : : : : WK PPR GEN SERVICE LRG GEN SVC EX LRG GEN SVC INTERRUPTIBLE TRANSPORT TRANSPORT TRANSPORT REF TOTAL SCHEDULE 101 SCH.111&112 SCH.121&122 SCH.131&132 SCHEDULE 146 IMCO/LiGNETICS POTLATCH PRES BILLING DETERMINANTS THERMS GD1 BLOCK 1 684 524 278 657 500 691 030 199 851 222 189 926 290 GD1 BLOCK 2 968,140 500 813,471 889 580 GD1 BLOCK 3 297 370 918 140 GD1 BLOCK 4 326,163 OTHER SUBTOTAL 131 328,405 51,684,524 544 167 357,303 691 030 199 851 035,660 815 870 NET SHIFTING ADJUSTMENT SUBTOTAL 131,328,405 684 524 544 167 357 303 691,030 199,851 035 660 54,815,870 GD1 ADJUSTMENT TO ACTUAL (491,471)(491,471) TOTAL BEFORE ADJUSTMENT 130 836 934 51,684 524 052 696 357 303 691,030 199,851 035 660 815,870 GA3 WEATHER & UNBILLED REV. ADJ.829 751 706,579 123 172 TOTAL PROFORMA THERMS 130 007,183 977 945 929 524 357 303 691 030 199 851 035 660 815 870 GD1 TOTAL BILLS 698,032 GD1 TOTAUMINIMUM BILLS 867 120 PROP BilLING DETERMINANT ADJUSTMENTS (Adjustment to Actual) THERMS GD1 BLOCK 1 706,579 398 GD1 BLOCK 2 143 990 GD1 BLOCK 3 301,083 GD1 BLOCK 4 OTHER 706 579 491,471 PROP BilLING DETERMINANT ADJUSTMENTS (Weather & Unbilled Revenue) THERMS GD1 BLOCK 1 637 GD1 BLOCK 2 907 GD1 BLOCK 3 116 903 GD1 BLOCK 4 OTHER 123,172 PROP BilLING DETERMINANTS THERMS GD1 BLOCK 1 50,977 945 233 896 500 691 030 199 851 222,189 40,926 290 GD1 BLOCK 2 816 243 500 813,471 889 580 GD1 BLOCK 3 879 384 918,140 GD1 BLOCK 4 326 163 OTHER SUBTOTAL 130,007,183 977 945 12,929 524 357,303 691,030 199,851 035 660 54,815 870 NET SHIFTING ADJUSTMENT TOTAL PROFORMA THERMS 130 007 183 977 945 929 524 357 303 691 030 199 851 035,660 815 870 GD1 TOTAL BILLS 698,032 GD1 TOTAUMINIMUM BILLS 867 120 Exhibit No, 147 Case No. A VU-04- A VU -04- D. Schunke, Staff 6/21/04 Page 1 of 4 WK PPR PRESENT RATES GEN SERVICE LRG GEN SVC EX LRG GEN SVC INTERRUPTIBLE TRANSPORT TRANSPORT TRANSPORT REF TOTAL SCHEDULE 101 SCHEDULE 111 SCHEDULE 121 SCHEDULE 131 SCHEDULE 146 IMCO/LIGNETICS POTLATCH (1) GB1 BASIC CHARGE $3. GB1 MONTHLY MINIMUM $97.$238. Schedule 150 BLOCK 1 PER THERM 27.186~27.186~27.186~24.370~(2.993~) BLOCK 2 PER THERM 27.186~27.186~ BLOCK 3 PER THERM 27.186~27.186~ BLOCK 4 PER THERM 27.186~ GB1 BLOCK 1 PER THERM 47.011~48-649~47.666~31.354~13.567~000~750~ GB1 BLOCK 2 PER THERM 47.011~47.011~7.426~100~ GB1 BLOCK 3 PER THERM 37-789~37.789~ GB1 BLOCK 4 PER THERM 36.098~ Note: Rates include Schedule 150 - Purchased Gas Cost Adjustment WK PPR PRESENT REVENUE GEN SERVICE LRG GEN SVC EX LRG GEN SVC INTERRUPTIBLE TRANSPORT TRANSPORT TRANSPORT REF TOTAL SCHEDULE 101 SCHEDULE 111 SCHEDULE 121 SCHEDULE 131 SCHEDULE 146 IMCO/LIGNETICS POTLATCH BILLING REVENUE BASIC CHARGE $2,289 545 289 545 MONHTL Y MINIMUM $696 759 $668 159 $28,600 BLOCK 1 $39,355,466 $37 824 106 $335,447 $15 360 $385 070 $444,092 $44,444 $306,947 BLOCK 2 022 017 831 538 $41,921 $134 668 $13,890 BLOCK 3 $5,716 191 $5,119,630 $596 561 BLOCK 4 $839 249 $839 249 ANNUAL MINIMUM ADJUSTMENT SUBTOTAL $51 919 227 $40,113 651 954 774 $1,521 691 $385 070 $444 092 $179,112 $320 837 NET SHIFTING ADJUSTMENT TOTAL BILLING REVENUE $51 919 227 $40,113,651 954 774 521 691 $385 070 $444 092 $179 112 $320 837 Exhibit No. 147 Case No. A VU-04- A VU -04- D, Schunke, Staff 6/21/04 Page 2 of 4 WK PPR STAFF PROPOSED RATES GEN SERVICE LRG GEN SVC EX LRG GEN SVC INTERRUPTIBLE TRANSPORT TRANSPORT TRANSPORT REF TOTAL SCHEDULE 101 SCHEDULE 111 SCHEDULE 121 SCHEDULE 131 SCHEDULE 146 IMCO/LIGNETICS POTLATCH (1) GB1 BASIC CHARGE $3.$200. GB1 MONTHLY MINIMUM $156.$385. WACOG & transportation BLOCK 1 PER THERM 53.546c,t 53.546c,t 53.546c,t 45.223c,t BLOCK 2 PER THERM 53.546c,t 53.546c,t BLOCK 3 PER THERM 53.546c,t 53.546c,t BLOCK 4 PER THERM 53.546c,t GB1 BLOCK 1 PER THERM 26.132c,t 24.644c,t 23.557c,t 11.308c,t 10.908c,t 000c,t 750c,t GB1 BLOCK 2 PER THERM -....c 22.833c,t 22.833c,t 7.426c,t 100c,t GB1 BLOCK 3 PER THERM 12.636c,t 12.636c,t GB1 BLOCK 4 PER THERM 10.767c,t WK PPR STAFF PROPOSED REVENUE GEN SERVICE LRG GEN SVC EX LRG GEN SVC INTERRUPTIBLE TRANSPORT TRANSPORT TRANSPORT REF TOTAL SCHEDULE 101 SCHEDULE 111 SCHEDULE 121 SCHEDULE 131 SCHEDULE 146 IMCO/LIGNETICS POTLATCH BILLING REVENUE BASIC CHARGE $2,306,345 289 545 $16,800 MONHTL Y MINIMUM 120 123 $1,073 861 $46 261 BLOCK 1 $41 818 218 $40 618 074 $390,644 $458 108 $44,444 $306 947 BLOCK 2 $3,106 513 914 801 $43 154 $134 668 $13 890 BLOCK 3 $5,822,420 214 772 $607 648 BLOCK 4 $852 893 $852,893 ANNUAL MINIMUM ADJUSTMENT SUBTOTAL $55,026 511 $42,907,619 203,435 549 956 $390 644 $474,908 $179 112 $320 837 NET SHIFTING ADJUSTMENT TOTAL BILLING REVENUE $55 026 511 $42,907,619 203,435 549,956 $390,644 $474,908 $179,112 $320 837 Proposed Overall Increase 98%97%78%86%1 .45%94%00%00% COS $55,026 511 $43 121,364 098,183 528,116 $379,886 $399 013 $179 112 $320 837 Proposed COS Index 100.00%99.50%101.16%101.43%102.83%119.02%100.00%100.00% Current COS Index 100.00%99.08%102.70%101.93%103.45%126.70% Average Rate Per Therm $0.42326 $0.84169 $0.71182 $0.65751 $0.56531 $0.11308 $0.04438 $0.00585 Per therm contribution to margin $0.30623 $0.17636 $0.12205 $0.11308 $0.11308 Exhibit No. 147 Case No. A VU-04- A VU -04- D. Schunke, Staff 6/21/04 Page 3 of 4 STAFF PROPOSED RATES BASIC CHARGE MONTHLY MINIMUM BLOCK 1 PER THERM BLOCK 2 PER THERM BLOCK 3 PER THERM BLOCK 4 PER THERM TOTAL GEN SERVICE LRG GEN SVC EX LRG GEN SVC INTERRUPTIBLE TRANSPORT TRANSPORT TRANSPORT SCHEDULE 101 SCHEDULE 111 SCHEDULE 121 SCHEDULE 131 SCHEDULE 146 IMCO/LiGNETICS POTLATCH (1 ) Exhibit No, 147 Case No. A VU-04- A VU -04- D. Schunke, Staff 6/21/04 Page 4 of 4 A VISTA UTILITIES IDAHO - GAS COMPARISON OF PRESENT & STAFF PROPOSED GAS RATES Present Rates(1l (a) $3.28 Basic Charge General Service Schedule 101Increase Staff Proposed Rates(1l(b) (c) $0,00 $3. All Therms - 74.197~/Therm 5.481 79.678 Large General Service Schedule 111 Presen~ Rates(1l Increase Proposed Ra~ 1 st 200 Therms - 75.836~/Therm Next 800 Therms - 74.197~/Therm Over 1 000 Therms - 64.975~/Therm 354 182 207 78,190 76,379 66.182 Minimum - $97.30/Month plus 27 ,186~/Therm Minimum - $156.38/Month Large General Service Schedule 121 Presen~ Rates(1l Increase Proposed Rates(1l 1 st 500 Therms - 7 4,852~/Therm Next 500 Therms - 74.197~/Therm Next 9 000 Therms - 64.975~/Therm Over 10 000 Therms - 63,284~/Therm 251 182 207 029 77.1 03 76.379 66.182 64.313 Minimum - $238,33/Month plus 27 .186~/Therm Minimum - $385,51 /Month Interruptible Service Schedule 131 Present Rates(1l Increase Proposed Rates(1l All Therms - 55.724~/Therm 807 56.531 Transportation Service Schedule 146 Present Rates(1l Increase Proposed Rates(1l No Basic Charge $200. OO/month $200.00 Basic Charge All Therms - 10.574~/Therm 334 10,908 (1) Rates include Purchase Gas Adjustment Schedule 150/ Exclude all other rate adjustments Exhibit No, 148 Case No. A VU-04- A VU -04- D, Schunke, Staff 6/21/04 CERTIFICATE OF SERVICE HEREBY CERTIFY THAT I HAVE THIS 21ST DAY OF JUNE 2004 SERVED THE FOREGOING DIRECT TESTIMONY OF DAVID SCHUNKE, CASE NO. A VU-04-l/A VU-04-, BY MAILING A COpy THEREOF POSTAGE PREPAID TO THE FOLLOWING: DA VID J. MEYER SR VP AND GENERAL COUNSEL VISTA CORPORATION PO BOX 3727 SPOKANE WA 99220-3727 KELLY NORWOOD VICE PRESIDENT STATE & FED. REG. AVIS T A UTILITIES PO BOX 3727 SPOKANE WA 99220-3727 CONLEY E WARD GIVENS PURSLEY LLP PO BOX 2720 BOISE ID 83701-2720 DENNIS E PESEAU, PH. D. UTILITY RESOURCES INC 1500 LIBERTY ST SE, SUITE 250 SALEM OR 97302 CHARLES L A COX EVANS KEANE 111 MAIN STREET PO BOX 659 KELLOGG ID 83837 BRAD M PURDY ATTORNEY AT LAW 2019 N 17TH ST BOISE ID 83702 '" S ECRE~ AR Y CERTIFICATE OF SERVICE