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Home My WebLink About20081024Yankel Direct.pdfLAW OFFICES OF W. MARCUS W. NYE RANDALL C. BUDGE JOHN A. BAILEY, JR. JOHN R. GOODELL JOHN B. INGELSTROM DANIEL C. GREEN BRENT O. ROCHE KIRK B. HADLEY FRED J. LEWIS ERIC L. OLSEN CONRAD J. AIKEN RICHARD A. HEARN, M.D. DAVID E. ALEXANDER LANE V. ERICKSON PATRICK N. GEORGE SCOTT J. SMITH STEPHEN J. MUHONEN BRENT L. WHITINGJUSTIN R. ELLIS JOSHUA D. JOHNSON JONATHON S. BYINGTON DAVE BAGLEY CAROL TIPPI VOLYN THOMAS J. BUDGE CANDICE M. MCHUGH JONATHAN M. VOLYN MARK A. SHAFFER RACINE OLSON NYE BUDGE & BAILEY CHARTERED 201 EAST CENTER STREET POST OFFICE BOX 1391 POCATELLO, IDAHO 83204-1391 TELEPHONE (208) 232-6101 FACSIMILE (208) 232-6109 www.racinelaw.net SENDER'S E-MAIL ADDRESS:elol§racinelaw.net October 24, 2008 Jean Jewell IPUC Commission Secretar P.O. Box 83720 Boise, Idaho 83720-0084 Re: IPC-E-08-10 Dear Mrs. Jewell: BOISE OFFICE 101 SOUTH CAPITOL BOULEVARD, SlJITE.208 BOISE, IDAHO 83702 TELEPHONE: (208) 39S~OOt 1 FACSIMILE: (208) 433"0167 IDAHO FALLS OFFICE 477 SHOUP AVENUESUITE203A IDAHO. FALLS, 1083402TELEPHONE:..(208) 528"6101 FACSIMILE: (208) 528-6109 COEUR D'ALENE OFFICE250 NORTHWESi BOULEVARD, SUITE t06A COEUR D'ALENE, 10 83814 TELEPHONE: (208) .765.6888 ALL OrFICES TÓLL rllEE (877) ;23;2-8101 LOUIS.F.RACINE (1917-2005) WILLIAM D. OLSON. OF COUNSEL. ~=o~ ~ ;¡ c,..ç'(: ;0m("rn, :: rn i::3 Enclosed for filing you will find the original and nine copies of the Direct Testimony of Anthony Yanel and Sidney Erwn. We are also submitting a searchable CD with the testimony and exhbits contained thereon. Than you for your continuing assistance. Sincerely, ERIC L. OLSEN ELO/nj Enclosures c: Service List (via mail and e-mail) RECEIVED îii080CT 21; PH 3: 40 IDAHO PLJ6.~¡S~'It\iii UTiLITIES COMNi¡I:,S ")l~ BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION IN THE MATTER OF THE APPLICATION ) OF IDAHO POWER COMPANY FOR ) AUTHORITY TO INCREASE ITS ) RATES AND CHARGES FOR ELECTRIC )SERVICE. )CASE NO. IPC-E-08-10 IDAHO IRRIGA nON PUMPERS ASSOCIATION, INC. DIRECT TESTIMONY OF ANTHONY 1. YANKEL OCTOBER 24, 2008 1 Q.PLEASE STATE YOUR NAME, ADDRESS, AND EMPLOYMENT. 2 3 A.I am Anthony J. YaneL. I am President of Yane 1 and Associates, Inc. My 4 address is 29814 Lake Road, Bay Vilage, Ohio, 44140. 5 6 Q.WOULD YOU BRIEFLY DESCRIBE YOUR EDUCATIONAL 7 BACKGROUND AND PROFESSIONAL EXPERIENCE? 8 9 A.I received a Bachelor of Science Degree in Electrcal Engieering from Caregie 10 Institute of Technology in 1969 and a Master of Science Degree in Chemical Engineerng from 11 the University of Idaho in 1972. From 1969 through 1972, I was employed by the Air 12 Correction Division of Universal Oil Products as a product design engineer. My chief 13 responsibilties were in the areas of design, star-up, and repair of new and existing product lines 14 for coal-fired power plants. From 1973 through 1977, I was employed by the Bureau of Air 15 Quality for the Idaho Deparent of Health & Welfare, Division of Environment. As Chief 16 Engineer of the Bureau, my responsibilities covered a wide range of investigative fuctions. 17 From 1978 through June 1979, I was employed as the Director of the Idaho Electrcal Consumers 18 Office. In that capacity, I was responsible for all organizational and techncal aspects of 19 advocating a varety of positions before various goverental bodies that represented the 20 interests of the consumers in the State of Idaho. From July 1979 though October 1980, I was a 21 parer in the firm ofYanel, Eddy, and Associates. Since that time, I have been in business for 22 myself. I am a registered Professional Engineer in the states of Ohio and Idaho. I have 23 presented testimony before the Federal Energy Regulatory Commission (FERC), as well as the 1 Yanel, DI Irrgators 1 State Public Utilty Commissions of Idaho, Montana, Ohio, Pensylvana, Utah, and West 2 Virginia. 3 4 Q. 5 6 A. 7 (Irrgators). 8 9 Q. 10 11 A. 12 13 14 15 16 Q. 17 CASE? 18 19 A. 20 21 22 23 ON WHOSE BEHALF ARE YOU TESTIFYING? I am testifyng on behalf of the Idaho Irgation Pumpers Association, Inc. WHAT IS THE PURPOSE OF YOUR TESTIMONY IN THIS PROCEEDING? My testimony wil address: · Disproportionate growth on the system · Irrgation Peak Rewards Program · Allocation of Sales For Resale and Purchase Power based on usage WHAT ARE YOUR CONCLUSIONS AND RECOMMENDATIONS IN THIS I make the following conclusions and recommendations: · There has been very rapid growt on the system for all customer classes except the Irrgators' load which has been flat for at least the last 25 years. The cost of this growth shows up in all aspects of the Company's cost strcture; Production, Transmission, and Distrbution. 2 Yanel, DI Irgators 1 · In spite of the lack of Irrgation growt, the Company's cost-of-service study 2 allocates disproportionate amounts of these costs to the Irgators. The 3 Irrgators have gotten more than the system average increase for at least the 4 last 15 years. 5 · If the Company's "Base Case" cost-of-serice study were modified to match 6 its margial cost allocation factors with the growt causing the marginal costs 7 (as opposed to historic usage biling determinants), the rate of retu for the 8 Irrgation class would more appropriately reflect the lack of Irgation 9 contrbution to the system growth and growth related costs. If the impact of 10 growth is recognzed, the Irrgation rate of retu would be over four times the 11 system average. Based upon a proper matching of the Company's marginal 12 costs allocation factors with growt (as opposed to historic biling 13 determinants), I recommend no increase in this case for the Irrgators. 14 · The Irrgation Peak Rewards Program is about to undergo major 15 improvements that should greatly increase paricipation levels and become a 16 major resource for Idaho Power to use in controllng its summer peak load. 17 These changes should be in place for next sumer's Irrgation season and 18 system peak loads. Any consideration of cost of serice and revenue 19 responsibilty should reflect the fact that there wil be major changes to the 20 system peak loads when these rates are in effect as well as the Irrgation 21 contrbution to those peak loads. 22 · The Company has historically allocated Sales For Resale revenues on a 23 simplistic basis (anual energy usage and/or generation demand 3 Yanel, DI Irrgators 1 responsibilty). Data and computing techniques are available today to match 2 these sales on an hourly basis with the cost causation the makes these sales 3 possible. An example is presented as to how this can be done and a 4 recommendation is made to consider such techniques for futue cases. 4 Yanel, DI Irrgators 1 DISPROPORTIONATE GROWTH ON THE SYSTEM 2 Q.HAS GROWTH ON THE IDAHO POWER SYSTEM BEEN UNIFORM? 3 4 A.No. For more than two decades there has been a major imbalance in the growth 5 on the Idaho Power system between customer classes. 6 7 Q.UPON WHAT DO YOU BASE YOUR STATEMENT THAT THERE HAS 8 BEEN AN IMBALANCE OF GROWTH ON THE SYSTEM? 9 10 A.Even the most casual obserer should note that for years there has been strong and 11 persistent growt on the Idaho Power system and that this growth has not occured in the 12 Irrgation load. This is most easily demonstrated by observing the following graph!: 7,000 Historic Growth 6,000 5,000 l 4,000 3,000 2,000 Irrigation 1,000 1980 1985 1990 1995 2000 2005 13 5 Yanel, DI Irrgators lOver the last 25 years, the Irrgation load has been basically flat-decreasing 2%; Residential 2 load has increased 54%; and the combined Commercial/Industral load has over doubled at an 3 increase of 124%. All customer classes, except the Irrgation class, have caused the phenomenal 4 growt on the Idaho Power system. This pattern is expected to continue? 5 6 Q.WHY DOES THIS GRAPH OF 25 YEARS OF HISTORICAL USAGE END 7 WITH2005? 8 9 A.The data for this graph came from the Company's 2006 Integrated Resource Plan 10 ("IRP"). I utilized the Company's IRP because it is a source of data where it is possible to get 25 11 years of historical data as well as projected usage, all in one place. The most recent Idaho Power 12 IRP is for 2006. Historical data from the Company's 2006 IRP only goes to 2005. There was a 13 2008 IRP Update, but it did not provide similar historical information. 14 15 Q.HAS THERE BEEN GROWTH IN UTILITY PLANT -IN-SERVICE? 16 17 A.Yes. In order to keep up with this growt, there have been signficant increases in 18 Plant-In-Service at all functions as demonstrated by the following graph3: 1 Historic usage data taen from pages 25,27,29,31 of Appendix A ofIdaho Power's 2006 IRP. 2 According to Appendix A, page 39 ofIdaho Power's 2008 Integrated Resource Plan Update, over the next 10 year Irrgation load is expected to decline slightly, while all of the other classes are expected to experience continued load growt.3 Data taen from FERC Form 1 for years 1981-2006. 6 Yanel, DI Irgators 1 1,800 Historic Plant in Service 1,600 ~1,400 ./ 1,200 Generation ~ 8 //Ô 1,000 --0 J ~~/~--a.Distribution~800)i ~~600 --~~400 ~.-----Transmission 200 0 I I I i i 1980 1985 1990 1995 2000 2005 2 3 In the last 25 years, Generation plant has increased $768 milion or 93%, Transmission plant has 4 increased $360 milion or 145% (more than doubled its 1981 level), and Distrbution plant has 5 increased the most by adding an additional $780 milion or 246% (over trpled its 1981 level). 6 Given the huge percentage growth in Distrbution Plant-In-Serice and the fact that the 7 absolute dollar magntude even exceeded that of new Generation plant, it is wortwhile to look at 8 these accounts in more detail: 7 Yane!, DI Irrgators 1 350 Historic Plant Account Values 300 OH conductor 250 ooct 200 gct "" 150)(lI 100 50 o 1980 1985 1990 1995 2000 2005 2 3 As can be seen from the above graph, the increase in plant-in-serice has occured in all aspects 4 of Distrbution Plant. What is not readily apparent from the above graph is the percentage 5 change in various accounts. The Overhead Conductor account has doubled, while the Poles and 6 Line Transformer accounts have trpled in the last 25 years. However, the Underground 7 accounts have gone up over 700% of their levels from 25 years ago. 8 9 Q.DOES THE COMPANY'S ALLOCATION METHODS AND COST OF 10 SERVICE STUDIES PROPERLY REFLECT THE IMPACT OF THESE GROWTH RATES 11 ON COSTS TO CUSTOMER CLASSES? 12 8 Yanel, DI Irrgators 1 A.No. IPCo witness Gale stated in his testimony in this case4 that the Company has 2 been advocating cost based rates: 3 Idaho Power has consistently advocated for the principle that rate spread among 4 the customer classes and for component pricing within the customer classes 5 should be primarly cost-based. Accordingly, the company's rateiaking 6 proposals have traditionally advocated movement towards cost-of-serice results 7 which assign costs to those customers that cause the Company to incur the costs. 8 Although IPCo tres to follow this policy with respect to the results produced by its cost of 9 serce studies, the Company's cost of servce study inappropriately allocates a signficant 10 portion of this growth to the Irrgation class. Given the obvious fact that growth and the cost of 11 growth are not being fueled by the Irrgators, the allocation of signficant portions of the cost of 12 this growth to the Irgators is on its face counter-intuitive. Additionally, the Company is not 13 properly signaling the rate schedules that are growing that their growt is expensive-thus, 14 promoting additional growth. 15 16 Q.PLEASE FURTHER EXPLAIN HOW THE RESULTS OF THE COMPANY'S 17 CLASS COST OF SERVICE STUDY ARE COUNTER-INTUITIVE. 18 19 A.As pointed out above, the trend that has been in place for more than two decades 20 is that the non-Irrgation load has increased, while the Irgation load has either stayed even or 21 decreased. The following lists the anual system peak demand data utilzed in both this case and 22 Case IPC-E-94-5 which used a 1993 test yearS (15 years ago): 4 See the direct testimony ofJohn R. Gale at page 23 lines 16-24. 5 The non-irgation data listed for Case IPC-E-94-5 does not include data for FMC. 9 Yanel, DI Irgators 1 Anual System Peak 1993 2008 % Change 2 Irrgation (kW) 572,219 610,726 6.7% 3 Non-Irgation(kW) 1,212,428 2,331,457 92.3% 4 As can be seem from above, the changes in load at the time of the single anual system peak are 5 strking. Over the last 15 years, the rate of growth for the non-irrgation customers has been at a 6 rate that is approximately 14 times greater than that for the Irrgators. 7 A similar pattern can be seen with respect to the anual energy consumption: 8 Anual Energy Usage 1993 2008 % Change 9 Irrgation (MW) 1,799,035 1,720,416 -4.4% 10 Non-Irrgation(MWH) 8,867,253 13,316,310 50.2% 11 As can be seem from above, the changes in annual energy usage follow a diverging pattern. 12 Over the last 15 years the Irrgation usage has decreased usage by almost 5%, while Non- 13 Irrgation usage has increased approximately 50%. As pointed out by Irgator witness Sidney F. 14 Erwin, the fact that there is a moratorium on new ground water rights in the Snake River Plain 15 Aquifer prohibits Irgation load from growing due to the lack of water. Although there has been 16 conversion of some flood irrgated land to sprinkler irrgation, much of ths limited growt has 17 been offset by more efficient irrgation methods being applied. For the other customer classes, 18 there are far less limitations to their continued growth as predicted by the Company. 19 20 Q.WHY IS THIS HISTORIC PRESPECTIVE OF BILLING DETERMINANTS 21 IMPORTANT? 22 10 Yanel, DI Irrgators 1 A.It has been an often repeated theme of this rate case as well as past rate cases that 2 growth on the system is causing cost increases and the corresponding need to seek rate increases 3 for the customers. As stated by Company President Mr. Keen in this case6: 4 Q. Are these actions alone suffcient to ensure a reliable and safe supply of 5 electrcity for your customers? 6 A. No. The need to expand infrastrctue and obtain new energy supplies 7 continues to grow. Our recently filed update of our Commission-accepted 8 Integrated Resource Plan, or "IRP", forecasts the addition of between 12,500 and 9 13,000 new customers per year over the 20-year planing period. Energy demand lOis forecast to grow about 30 average megawatts per year with a 70 megawatt-per- Il year increase in peak demand levels - a growt rate that would be greater if not 12 for our demand-side management efforts during the period. These trends wil 13 require continuing expansion of generation and deliver systems and energy 14 effciency programs. The IRP details our need to add 650 megawatts of supply- 15 side capacity and 225 megawatts of transmission capacity from 2008 through 16 2012. 17 18 Given the substantial growth on the Idaho Power system and the cost of that growth, one would 19 expect that the cost of that growth would be borne by the customers that are causing that growth. 20 Contrary to this premise, the Company's cost of service studies over the last 15 years have 21 proposed to allocate disproportionate increases to the Irrgators in order to pay for the cost of 22 growth of other customers. The following is a listing of the percentage increases recently sought 23 by Idaho Power and the percentages increases that the Company's costs of serce studies 24 assigned to the Irrgators as well as Residential and General Servce (secondar): 25 26 27 28 29 30 Overall Increase to Increase to Increase to Case No.Increase Irrgators Residential GS (Sec.) IPC-E-03-13 7 17.68%67.10%13.38%8.00% IPC-E-05-288 7.82%27.03%2.76%7.32% IPC-E-07-089 10.35%42.64%0.11%9.14% IPC-E-08-10Io 9.89%32.38%2.01%9.44% 6 See direct testimony of J. Lamont Keen at page7 lines 1-17. 7 Exhibit 41 page 1 line 233 8 Exhibit 44 page 1 line 53 9 Exhibit 45 page 1 line 53 10 Exhibit 57 page 1 line 53 11 Yankel, DI Irrgators 1 Note that in spite of the Irgators not causing any growt or growth related costs, the 2 Company's cost of serice study attempts to give Irrgators percentage rate increases that are 3 signficantly above the system average, while those same cost of servce studies have always 4 shown the Residential customers and the General Servce (secondary) customers as needing less 5 than the average rate increase. Clearly, these Company cost of serice studies have been 6 producing counter-intuitive recommendations with respect to the Irrgation customers. 7 8 Q.IS THE ALLOCATION METHODOLOGY IN THE COMPANY'S COST OF 9 SERVICE STUDY IN THIS CASE THE SAME AS THAT FROM 15 YEARS AGO? 10 11 A.Generally speaking, yes. There have been some minor changes compared to 15 12 years ago, but the allocation methodology used by the Company in this case under Exhibits 54- 13 58 (refered to by the Company as its "Base Case") is similar for the major allocators (DlO, DB, 14 and E 10). If anyting, the allocation methodology under the Company's Base Case may be more 15 tolerant of the lack of Irrgation growt than was the allocation methodology used 15 years ago. 16 In spite of the Company's proposed method in this case being "more tolerant of the lack of 17 Irrgation growth", it is stil wide-of-the-mark of fairly allocating the cost of growth to those 18 classes that have been growing and thus, causing substantial cost increases to the system. 19 20 Q.HOW DO THE COSTS ALLOCATED TO THE IRRIGATORS AND OTHER 21 CUSTOMERS IN THIS CASE, COMPARED TO THE COST OF SERVICE STUDY 22 PROVIDED 15 YEARS AGO, REFLECT THE LACK OF GROWTH OF THE IRRIGATION 23 CLASS AND THE SIGNIFICANT GROWTH IN OTHER CUSTOMER CLASSES? 12 Yanel, DI Irrgators 1 2 A.A comparison of the level of costs allocated to Irrgators in this case with those 3 allocated 15 years ago, demonstrates the counter-intuitive natue of these studies when growth 4 and the cost of growth is not addressed in the allocation factors. A comparson of the allocated 5 Production rate base between this case (IPCo' s "Base Case") and the case 15 years ago reveals 6 the following: Productionll (x$1000)1993 2008 % Change Irrgation $164,667 $230,329 39.9% Non-Irrgation $847,877 $1,533,152 80.8% 7 8 9 10 Under the Company's allocation method, the Production plant rate base attrbuted to Irgators 11 has increased by 40% and the percentage of new Production plant attrbuted to Irgators (whose 12 load has been virtally stagnant) is half the percentage increase that has been allocated to all of 13 the customer classes that have been experencing rapid growth. 14 The counter-intuitive natue of the Company's allocation methods with respect to this 15 lopsided growth are even better observed with respect to the rate base associated with 16 Transmission plant. A comparson of the allocated Transmission rate base between this case 17 (IPCo' s "base case") and the case 15 years ago reveals the following: 18 Transmission12 (x$1000) 19 Irrgation 1993 $41,271 2008 % Change $ 89,016 115.7% 20 Non-Irgation $207,152 $597,840 188.6% II 1993 data comes from Case No. IPC-E-94-5, Company Exhibit 32, pages 3 and 4. The 2007 data comes from Case No. IPC-E-08-1O, Company Exhibit 55 (base case), page 3.12 1993 data comes from Case No. IPC-E-94-5, Company Exhibit 32, pages 3 and 4. The 2007 data comes from Case No. IPC-E-07-08, Company Exhibit 55 (base case), page 3. 13 Yanel, DI Irgators 1 In spite of the fact that the overall usage of the Irrgators has been flat and their growth in 2 contrbution to the anual system peak has been virtally non-existent in comparison to the other 3 customer groups, the Company's allocation method is giving Irgators over double the 4 transmission rate base it had 15 years ago and approximately the same percentage increase in 5 new Transmission plant that it is giving all other customer classes. 6 The counter-intuitive nature of the Company's allocation methods with respect to this 7 lopsided growth can also be observed with respect to the rate base associated with Distrbution 8 plant. A comparison of the allocated Distrbution rate base between this case (IPCo's "base 9 case") and the case 15 years ago reveals the following: 10 Distrbution 13 (x$1000)1993 2008 % Change 11 Irgation $105,394 $187,260 $425,080 $1,070,312 77.7% 12 N on- Irrgation 151.8% 13 Once again, in spite of the fact that the overall energy usage of the Irrgators has been on the 14 decline and their growt in contrbution to the anual system peak has been virtally non- 15 existent in comparson to the other customer groups, the Company's allocation method in this 16 case is giving almost double the dollar amount of Distrbution plant-in-serce to the Irgators 17 that was given 15 years ago even though there was no growth by the Irrgators. The Company's 18 allocation method has given approximate half of the percentage increase in new Distrbution 19 plant to the Irgators that it is giving all other customer classes. One would expect only a small 20 amount of this growt in Distrbution plant went to serve Irrgation customers. 21 13 1993 data comes from Case No. IPC-E-94-5, Company Exhbit 32, pages 3 and 4. The 2007 data comes from Case No. IPC-E-08-10, Company Exhibit 55 (base case), page 3. 14 Yanel, DI Irgators 1 Q.WAS THE WORKSHOP THAT WAS INITIATED AS A RESULT OF THE 2 2003 CASE ABLE TO COME TO ANY CONCLUSIONS REGARDING THE TREATMENT 3 OF THE ALLOCATION OF THE COSTS ASSOCIATED WITH THIS GROWTH? 4 5 A.Although there was general consensus among the workshop paricipants on a 6 number of issues, the only agreement regarding the treatment of growt in the Company's cost of 7 serce study is that there is a disconnect between the classes that were growing and causing the 8 costs to be incured and the allocation of those costs. Regarding whether new growt was 9 properly covering its cost of serice, "The Parties' Final Report in IPC-E-04-23" stated: 1 0 Most of the workshop time was devoted to discussion of this issue. The paries 11 agreed that there was something inherently troubling with the way costs. 12 associated with growth. were allocated. This is evidenced by the relatively large 13 increase in revenue requirement allocated to customers whose load and energy 14 requirements were unchanged or grew only slightly. While there was agreement 15 that the cost of growth did not necessarly get allocated to the customer classes 16 that grew. we were unable to devise a techncal remedy to the allocation 17 procedure that would also satisfy the courts. The paries were unable to devise 18 and agree to a cost-of-service allocation methodology that would properly allocate 19 the cost of growth, without making a distinction between new and old customers. 20 Even a search of what others, around the countr, were doing produced little in 21 the way of an acceptable solution. Therefore, it was concluded that the only 22 remedy is a policy solution. The paries were not wiling to agree to the 23 pariculars of such a policy and recommend that the Commission formulate such a 24 policy in the next rate proceeding. (Emphasis added) 25 26 Q.WERE THE WORKSHOP PARTICIPANTS ABLE TO DEVELOP A 27 CONSENSUS POSITION THAT DEFINED THE COST IMPACTS OF GROWTH? 28 29 A.No. As pointed out above, the workshop participants were not able to develop a 30 consensus method for allocating the cost of growth in a maner that was acceptable to all parties. 31 The problem with attempting to develop a consensus was recognzed by varous paricipants at 15 Yanel, DI Irrgators 1 the workshop. Although there was general consensus that there was something inherently very 2 wrong with the present allocation scheme as related to its ability to allocate the cost of growt, 3 no one felt that they could go back to their clients and admit that they agreed to a methodology 4 that would cost their client more money-this decision was left to the Commission. 5 6 Q.DOES THE COMPANY'S APPROACH TO RATEMAKING AND COST 7 ALLOCATION ATTEMPT TO REFLECT COSTS? 8 9 A.That is the Company's stated goal, although that may not be the result. The 10 classification and allocation used by the Company, only looks at half of the cost causation 11 equation-it assumes a steady state situation or one with even growth across all classes. The 12 NARUC Electrc Utilty Cost Allocation Manual makes a general statement that is right on target 13 in this situation: 14 The common objective of the methods reviewed in the following two 15 pars is to allocate production plant costs to customer classes 16 consistent with the cost impact that the class loads impose on the 17 utility system. (emphasis added)14 18 19 As a general statement, I believe all parties would agree with ths NARUC policy. As 20 demonstrated above, there has been a tremendous amount of growt on the system over the last 21 25 years with associated costs to support that growth. For all practical puroses, the Irgators 22 have not paricipated in that rapid growth and were not the cause of the costs associated with that 23 growth. However, as has been demonstrated above, the Company's cost of servce studies do not 24 address the dispraportionate cost af growt and. thus. do not accomplish this goal. 25 16 Yanel, DI Irgators 1 Q.is THE COMPANY ADVOCATING THE SAME GENERAL ALLOCATION 2 METHODOLOGY IN THIS CASE AS IT DID OVER THE PAST 15 YEARS? 3 4 A.No. Although the Company provided as its Base Case an allocation methodology 5 that is similar to what it has proposed in the past, it is favoring a new classification/allocation 6 method in this case. The results of the Company's Base Case are contained in Mr. Tatu's 7 Exhibit 57. The new method favored by Mr. Tatum and the Company, classifies/allocates 8 Production costs based upon function (base, intermediate, and peak) during the thee sumer 9 months. The results of the Company's preferred method are contained in Mr. Tatu's Exhibit 10 66. The Company is not proposing any changes to its Transmission, Energy, or Distrbution 11 allocators. Thus, there is ver little overall change. 12 13 Q.is THE NEW ALLOCATION METHOD ADVOCATED BY THE COMPANY 14 FOR PRODUCTION RELATED COSTS AN IMPROVEMENT OVER THE PAST METHOD 15 THAT IT ADVOCATED? 16 17 A.Only very marginally. This new method only addresses Production cost and it 18 stil suffers from the same shortcomings as the Company's past studies-it allocates costs on a 19 stagnant basis, with no recogntion of the impact of growth on costs. This new method stil 20 suggests that the Irrgation customers pay a substantial amount for the cost of growth for which 21 they have not caused. 22 14 Electrc Utilty Cost Allocation Manual, published by the National Association of Regulatory Utilty Commissioners 1992 at page 39. 17 Yanel, DI Irgators 1 Q.DOES THE COMPANY BASE CASE ALLOCATION METHODOLOGY 2 RECOGNIZE THE NEED TO RECOGNIZE GROWTH IN ITS ALLOCATION 3 METHODOLOGY? 4 5 A.Although the Company's Base Case allocation methodology falls short of 6 recognzing the disparty of growt on the system, it has been stated that it is the Company's 7 intention to do so. In Case IPC-E-05-28 Company witness Brilz1S offered the following with 8 respect to the Company's thoughts regarding the Base Case methodology: 9 Q. What is the reasoning for using marginal cost weightings in the derivation of 10 the demand-and energy- related allocation factors? 11 12 A. The use of marginal cost weighting is intended to strke a balance between 13 backward-looking costs already incurred and forward-looking costs to be incured14 in the futue. 15 16 The exact same languge appears in Mr. Tatu's testimony in the 2007 rate case16. Mr. Tatu 17 provides very similar testimony in this case. 1 7 The intent is appropriate-the execution falls 18 short of the goal. 19 The balance between historic and forward looking costs that is strck in the Company's 20 study is 50% based upon an unweighted 12-CP allocation that is designed to reflect today's share 21 of cost causation on the system18. The other 50% of the allocation factor purorts to reflect 22 forward-looking costs and this is where the major disconnect occurs. The Company 23 inappropriately defines forward-looking costs using the same test-year 12-CP usage 24 characteristics (present day usage) and combines it with marginal weighting factors that reflect is Case No. IPC-E-05-28, witness Brilz at page 19. 16 Tatu testimony in Case No. IPC-E-07-08, page 25, line 10. 17 Tatum testimony in Case No. IPC-E-07-08, page 36, lines 2-4. 18 For puroses of ths discussion, I accept this par of the Company's method. However, this approach ignores the lopsided growt that has taken place for over two decades on the system. 18 Yanel, DI Irrgators 1 "forward-looking costs to be incured in the futue" in order to meet growth. Thus, the Irrgators 2 (as well as all classes) get assigned costs, based upon weighting factors designed to reflect 3 growt that is going to be incured by the System in the futue, but not based upon the 4 usage/growth that is going to Create those costs. Thus, unrealistic results occur where the 5 Irrgation load is stagnant or decreasing, but the cost of the system ~owt is being assigned to it. 6 not based upon futue growt of the Irrgators, but based upon the present usage of the Irrgators. 7 8 Q.HOW COULD THE COMPANY'S BASE CASE ALLOCATION 9 METHODOLOGY BE BETTER ALIGNED TO REFLECT "BACKWARD-LOOKING COSTS 10 ALREADY INCURRD AND FORWARD-LOOKIG COSTS TO BE INCURRD IN THE 11 FUTURE"? 12 13 A.The simplest way to correct the Company's Base Case study would be to continue 14 to define "backward-looking costs" based on test year usage levels and "forward-looking costs" 15 at the anticipated increase in usage levels in the Company's IR. The "backward-looking costs" 16 would simply be costs as they exist today and allocated on the basis of today' s energy or 12-CP 17 as is presently done in the Company's "base" cost of serce study. The "forward-looking costs" 18 would be developed using the same weighting factors used by the Company associated with the 19 cost of the anticipated growth, but would be allocated on the basis of only the wowt that is 20 anticipated from each rate schedule over a futue ten year period. The relative share of historic 21 costs and anticipated costs related to growth would then be averaged using the Company's 22 existing procedure in order to develop a composite allocation factor for use in spreading test year 23 costs for allocation puroses. In this maner, the methodology would be exactly the same as the 19 Yanel, DI Irrgators 1 Company's Base Case, but the marginal costs would be tied to the marginal/new usage and not 2 to the present level (status quo) of usage. 3 4 Q.HOW COULD THE CHANGE THAT YOU PROPOSE BE IMPLEMENTED 5 TO THE COMPANY'S COST OF SERVICE STUDY IN ORDER TO INSURE THAT THIS 6 COUNTER-INTUITIVE RESULT DOES NOT CONTINE IN THE FUTURE? 7 8 A.One very simple change could be made. Instead of combining the Company's 9 growth related weighting factors with existing biling determinants, they could be combined with 10 forecasted growth~making an apples-to-apples comparson. 11 The Company's 2006 IRP19 that sered as a basis for developing the weighted cost 12 factors can also serve as the source of the data for the forecasted growth as well. In Exhibit 301, 13 I have simply modifed the Company's allocation weighting procedure to apply the marginal cost 14 weightings developed by the Company to only the growth that is expected over the next ten 15 years20. For example, the Company's Exhbit 59 page 1 takes the May normalized demand for 16 the Residential class of894,322 and multiplies it by a weighting of 10.41 in order to develop a 17 weighted demand of9,309,897. The starting figue of 894,322 is a test year value and not 18 reflective of the growth that wil take place on the system. Only the future growth in Residential 19 load should be used for this calculation. 19 This is the last IRP where a full range of forecasts and data was provided. The 2008 Update did not contain detailed data to break out growt by grouping.20 A ten year growt horizon was chosen to give some stability to the numbers without forecasting out so far that reliabilty concerns would be raised. Although a five year growt horion would have produced more beneficial allocators for the Irrgators, it was felt that a ten year growt horizon would be preferable. 20 Yanel, DI Irrgators 1 According to the Company's 2006 1R21, the average load for the Residential class wil 2 increase from 4,865,000 to 5,811,000 biled MW or 19.45% between 2006 and 2016. Thus, 3 instead of using the Company's biling unit of 894,322, a value for expected growt must be 4 used. The expected growth for Residential load in May can be estimated at 173,946 MW 5 (894,322 MW x 0.1945) over the next ten years. This value of 173,946 MWh should be 6 multiplied by the Company's weighting factor of 10.41. Similar adjustments to only include the 7 growth portion of each class' load in the Company's method needs to be made. 8 9 Q.DID YOU PROPOSE THIS MECHANISM AS A MEANS OF REFLECTING 10 THE COST OF GROWTH TO THE WORSHOP IN CASE IPC-E-04-23? 11 12 A.No. The proposal I made to the Workshop was one that looked backward and 13 tred to capture the amount of growth and the cost of growth that took place over the previous 25 14 years. The Workshop was not able to come to an agreement regarding that proposed 15 methodology as a means of properly allocating the cost of growt. The methodology that I am 16 proposing here is forward looking and it matches the futue margial costs the Company 17 employs in its cost of serice study with futue growth. It does not attempt to separate "old 18 electrons" from "new electrons" or "new customers" from "old customers." 19 20 Q.WHAT GROWTH PERCENTAGES DID YOU INCORPORATE INTO YOUR 21 REVISION OF THE COMPANY'S BASE CASE COST OF SERVICE STUDY? 22 21 Idaho Powers 2006 IR-Sales and Load Forecast page 26. 21 Yankel, DI Irrgators 1 A.Using the Company's 2006 IR22, the following growt percentages were 2 calculated: 3 Residential 19.45% 4 Commercial (Sch. 7,9,40,42)30.04% 5 Industral (Sch. 19)27.24% 6 Irrgation 1.03% 7 Special Contracts 9.38% 8 I utilzed these percentages as the basis for calculating the amount of growth (beyond test year 9 biling deterinants) associated with the Generation and Transmission plant (allocators DI0, 10 D13, and ElO). I made no calculation to reflect the growth in Distribution plant that is larger 11 than the growth in either Generation or Transmission plant. 12 13 Q.WHAT is THE IMPACT ON THE COMPANY'S BASE CASE COST OF 14 SERVICE STUDY WHEN ITS GROWTH RELATED WEIGHTING FACTORS ARE 15 APPLIED TO FORECAST GROWTH AS OPPOSED TO HISTORICIPRESENT USAGE AND 16 HOW DO THOSE RESULTS COMPARE WITH THE BASE CASE STUDY IN THE 17 COMPANY FILING? 18 19 A In spite of the fact that this change is only directed at 50% of the allocation factor, 20 as can be seen from Exhibit 302, there is a major difference between the indexed rates of retu 21 that result from using weighting factors that are properly aligned with expected growth, 22 Idao Powers 2006 IR-Sales and Load Forecast pages 26-36 22 Yankel, DI Irrgators 1 compared to the Company's Base Case study that does not link marginal cost weighting factors 2 with growt. The indexed rates of return for the major rate schedules are summarzed below: 3 Study Res. Sch. 9 (s) Sch. 19 Irr. 4 Growth Corrected23 1.309 -0.1 73 ~0.211 4.574 5 Company's Base Case24 1.231 1.011 0.789 0.505 6 Although the difference between these two cost of serice rus is quite large for some rate 7 schedules, it should come as little surrise. It has been well recognzed by virtally all parties 8 that the Company's present allocation method does not properly address the cost of growt and 9 the fact that for at least twenty-five years the Irrgators have been getting saddled with costs that 10 they have not placed upon the system. In fact, the Irgators have often gotten rate increases 11 larger than the system average. 12 By way of contrast, the Growth Corrected study follows more intuitive logic. The growth 13 on the system over the last two-plus decades has not been even across all classes. Irrgation load 14 has been virtally flat, Residential load has increased rapidly, but not as rapidly as Commercial 15 and Industral load. Given the growt in average system load25 of20.7% that is predicted over 16 the next ten years in the 2006 IRP, any rate group that would be growing less than the average 17 should be getting a smaller share (compared to its size) of the marginal costs, while those 18 growing faster should get a higher percentage. The Irrgation growth is essentially zero and 19 Special Contract growth is less than the average, so this Growt Correction increases the rate of 20 retu for those classes over that produced by the Company's Base Case study. Residential 21 growth is about the system average, so there is little impact of using the Growth Corrected 23 Irgation Exhbit 301, line 38. 24 Company Exhibit 55, page 1, line 52. 25 Idaho Powers 2006 IR Sales and Forecast at page 36 shows sales in 2016 of 16,817 GWh compared to 13,938 GWh in 2006 for a difference of20.7%. 23 Yanel, DI Irrgators 1 method compared to the Company's Base Case. The Commercial and Industral load growth is 2 above average system growth so the Commercial and Industral customer's rate of return is 3 lowered. Given the fact that the Corrected Growt cost of serice ru recognizes the link 4 between growt and the growth related weighting factors, the resulting indexed rates of retu 5 are quite logical: 6 · The Residential growth rate is somewhat less than the system average; ther~fore, the 7 indexed rate of retu goes up a little when compared to the Company's Base Case. 8 · The Commercial growth rate is signficantly above system average; therefore, the 9 indexed rate of return for Schedule 9 signficantly drops when compared to the 10 Company's Base Case. 11 · The Industral growth rate is above system average (but not as much as Commercial); 12 therefore, there is a substantial drop in the indexed rate of return for Schedule 19 when 13 compared to the Company's Base Case. 14 . The Irgation growth rate is essentially non-existent; therefore, the indexed rate of return 15 goes up a great deal when few of the growth related costs are allocated to it compared to 16 the Company's Base Case. 17 18 Q.DO THE RESULTS OF THE COST OF SERVICE STUDY IN EXHIBIT 302 19 REFLECT THE GROWTH DIFFERENTIAL THAT IS ASSOCIATED WITH THE 20 DISTRIBUTION SYSTEM? 21 22 A.No. Exhbit 302 only reflects changes to the Company's cost of servce study to 23 reflect growt on the Generation and Transmission system. Over the last 25 years, the growth in 24 Yanel, DI Irrgators 1 Plant-in-Servce associated with the Distribution system has been greater than both the 2 Generation and Transmission system. A methodology needs to be adopted for addressing the 3 growt on the Distrbution system aswell. It should be remembered that not only have the 4 Irgators had very little impact for the past 25-plus years on the cost of the Company's 5 distribution plant, the Irgators have virtally nothing to do with the costs associated with the 6 Company's Underground Distrbution costs. 7 8 Q.THE GROWTH FACTORS THAT YOU INPORPORATED INTO THE 9 COMPANY'S STUDY ARE BASED UPON ENERGY GROWTH AND NOT DEMAND. is 10 THIS A PROBLEM? 11 12 A.No. First, there is only energy data available in the Company's 2006 IRP 13 regarding forecast usage. Admittedly, the use of forecast demand levels by rate schedules would 14 have a higher appeal, although not necessarly be more accurate. If demand forecasts by class 15 become available, I have no problem substituting that data. 16 Second, the impact of using demand as opposed to energy values may give the 17 appearance of being more accurate, but in the overall scheme of things, growth in energy and 18 growt in demand are highy (although not 100%) correlated with each other. The fact that all 19 classes are undergoing signficant growth, while the Irrgator load is virtally stagnant, is the 20 major factor involved. Once this watershed difference is recognzed, the rest is simply icing on 21 the cake. 22 Third, I am not making a proposal to right all of the wrongs that have occurred over the 23 last 25 years because the Irrgators have been penalized for costs that they did not cause. I am 25 Yanel, DI Irrgators 1 simply trng to get recogntion of the problem and begin to make minor corrections as we 2 continue to move through a perod of rapid growth on the system by most, but not all, classes of 3 customers. 4 5 Q.HOW SHOULD THE RESULTS OF EXHIBIT 302 BE UTILIZED FOR 6 PURPOSES OF THIS CASE? 7 8 A.The issue of addressing growth in the Company's cost of serce study is a new 9 direction for the Commission, and one that generally has not been faced by other commissions 10 across the countr. As the Final Report in the IPC-E-04-23 Workshop stated: "The paries 11 agreed that there was something inherently troubling with the way costs, associated with growth, 12 were allocated." As recognzed at the Workshop, the cost causation of growt is indisputable 13 and the lack of growth on the par of the Irrgators is indisputable as well. Recognzing that the 14 Commission moves cautiously (but deliberately) in these matters, I recommend that Exhbit 302 15 be used to generally direct the Commission's ordered rate spread in this case. 16 17 Q.BASED UPON THE GENERAL RESULTS OF EXHIBIT 302, WHAT 18 PORTION OF THE RATE INCREASE IN THIS CASE DO YOU RECOMMEND FOR THE 19 IRRIGATORS? 20 21 A.Over the last several rate cases, the Irrgators have been given the same or a 22 higher percentage increase than the system average. These increases have been given because 23 the Company's cost-of-serice studies have never addressed the disproportionate growth and 26 Yanel, DI Irrgators 1 associated costs between the classes. There was no growth on the par of the Irgators to cause 2 the costs to be incured that were associated with the rate increases being sought. The following 3 represents a brief picture of the increases that have been given to the Irrgators because this 4 disproportionate growt and cost causation has not been recognzed: 5 Case # Order # Ave. Increase Irrgation Increase 07-08 30508 5.20%5.65% 05-28 30035 3.20%3.20% 03-13 29505 5.20%13.95% 94-05 25880 4.19%10.23% 6 7 8 9 10 11 Over the last 10-plus years, the Irrgators have gotten well over the average rate increase, in spite 12 of the fact that they have not been causing the growt and the need for the rate increases on the 13 system. Based upon the greater than average increases which have been given to the Irrgators in 14 the past and the results of the simple correction/alignent of marginal costs with the growt 15 causing those costs which demonstrates26 that the Irgators should be given a signficant 16 decrease in rates; I recommend that the Irgators be given no increase in this case. I recommend 17 that the Residential class be given the average rate increase, and that Schedules 9 and 19 be 18 given larger than average increases. 19 20 Q.WHY SHOULD THERE BE ANY GROWTH ADJUSTMENT IN A COST OF 21 SERVICE STUDY WHEN EVEN WITH RATE SCHEDULES THERE WILL BE SOME 22 CUSTOMERS CAUSING THE GROWTH WHILE OTHERS ARE NOT? 23 24 A.Just because one may not wish to set rates on the basis of individual customers 25 that are causing the growth, this is no excuse for ignoring the larger pictue that signficant 27 Yanel, DI Irrgators 1 growth is taking place, and that growth is well defined on a class or rate schedule leveL. Rates 2 have always been set for a group of similarly situated customers and not on the paricular 3 characteristics of individual customers, unless that customer was very large and unique. It is also 4 my understanding that there are possible discrimination problems when seeking to charge 5 individual customers within a class different rates based upon when they first took service. With 6 respect to this prohibition, I am not proposing a difference of rates among individual customers 7 within a class based on growt, but the assignent of growth related costs to the classes that are 8 causing those growth related costs. From that perspective, my adjustment is essentially the same 9 as that proposed by the Company when it used marginal cost weighting factors in order to 10 allocate production and transmission plant. 11 Additionally, growth is not a simple question of defining who are the new customers. 12 Growt in load is taking place both because of new customers as well as because of increased 13 usage by existing customers. 14 At this time, the Irgators are looking for some recogntion by the Commission (as was 15 given by the Workshop from Case IPC-E-04-23) that there is "something inherently troubling 16 with the way costs. associated with growth. were allocated." Some initial attempt to recognze 17 this problem in the allocation of revenue requirement in this case would greatly move this 18 discussion forward, without causing a major disruption in class revenue requirement in this case. 26 Exhibit 302 line 43 28 Yanel, DI Irgators 1 IRRGATION PEAK REWARDS PROGRAM 2 Q.is THERE SOMETHING NEW HAPPENING WITH RESPECT TO THE 3 COMPANY'S IRIGA nON PEAK REWARS PROGRAM? 4 5 A.Yes. The Company, Irrgators and the Staff have been meeting to discuss 6 possible improvements in ths program for the benefit ofal!. A new program, modeled off of the 7 "company option" load management program in the PacifiCorp serice area, wil soon be 8 brought before the Commission with the hope of having the program in place before the 2009 9 Irrgation Season. The Irrgators are ver supportive of this program as well as the one offered in 10 the PacifiCorp serice area that interrpts electrcity to irrgation pumps at the Company's option 11 durng the sumer super-peak hours as opposed to just on designated days of the week as the 12 current program does. The Irrgation Peak Rewards Program is a workable program that 13 produces tangible benefits for the Company as well as all ratepayers. 14 15 Q.HOW MUCH BENEFIT CAN BE EXPECTED OUT OF THIS NEW PEAK 16 REWARS PROGRA? 17 18 A.Both the Irgators and the Company are hopeful that this new "company option" 19 program wil be very successful for the Irrgators and the system as a whole. The PacifiCorp 20 service area in Idaho has an Irrgation load during the anual system peak of approximately 255 21 MW. Under ths new program PacifiCorp has signed up approximately 215 MW of Irgation 22 load that it can interrpt at any time (presumably at peak times for the Company). PacifiCorp is 23 stil working with this program in order to get the maximum benefit from it. Unlike the previous 29 Yankel, DI Irrgators 1 program that PacifiCorp had or the Peak Rewards program that Idaho Power presently has, 2 interptions are only occurrng when the Company needs the electrcity and not merely 3 occurng because a clock states that the designated day and designated time have arved for an 4 interrption-irrespective of need. With PacifiCorp having control over approximately 85% 5 (215 MW / 255 MW) of its Irgation load, great strdes can be made in the reduction of costs 6 and the reduction of peaking resources. 7 According to Idaho Power's filing in this case, the IPCo Irrgators' contrbution to the 8 anual coincident peak is approximately 650 MW. I do not expect to see 85% of the IPCo 9 Irgation load on this new Peak Rewards program, but if there was even 50% paricipation, this 10 would yield a peak reduction capabilty of325 MW. By comparson, Idaho Power's present 11 Peak Rewards program has only been yielding approximately 40 MW of reduction on a system 12 where the Irrgation load is over 2.5 times larger than that on the PacifiCorp system. 13 14 Q.WHAT BENEFIT DOES THE IRIGATION PEAK REWARDS PROGRAM 15 PROVIDE TO THE SYSTEM? 16 17 A.On July 11, 2007 Quantec issued a Report to PacifiCorp (Rocky Mountain 18 Power) entitled "Assessment of Long- Term, System-Wide Potential for Demand-Side 19 and Other Supplemental Resources". Ths Report was designed to (and virtally did) 20 cover all aspects of DSM or alternative resources. The Irgation Load Curtailment 21 program was viewed as one of only thee "firm" DSM options that represent a Class 1 22 resource. Of these three Class 1 options, the Irgation Load Curailment program had the 23 lowest costs per unit of avoided capacity and in fact these costs were calculated to be less 30 Yanel, DI Irrgators 1 than half of the cost of the next closest option (direct load control of air conditioners). 2 The Irgation Load Curtailment program was calculated to have an avoided cost of 3 capacity in the Rocky Mountain Power region of $98/kW -year. 4 5 Q.HOW APPLICABLE TO IDAHO POWER is THAT REPORT'S AVOIDED 6 CAPACITY FIGURE OF $98IKW-YEAR FOR ROCKY MOUNTAIN POWER? 7 8 A.Although these are different utilties, they operate in the same general market, and 9 in ths case, both operate in souther Idaho. According to the Company's 2006 IR, the 10 following resources are being pursued with the associated costs: 11 12 13 14 15 16 17 18 19 $/kW -month27 170 MW Simple Cycle CT (non-fuel) $5.53 100 MW Wind $16.40 50 MW Geotheral $33.68 $/kW-year $69 $197 $404 Expansion of DSMResidential Existing Const. $5.34 $64 Commercial Existing Const. $10.15 $122Industral Efficiency $10.26 $123 Based upon these options that IPCo is pursuing, the $98/kW -year figue is a good representation 20 of the avoided cost of a program like the Irrgation Peak Rewards program. 21 22 Q.WHAT WILL BE THE COST OF THE NEW IRRIGATION PEAK REWARDS 23 PROGRAM? 24 27 Levelized cost of generation taken from IPCo's 2006 IRP, Appendix D, page 59. Levelized DSM costs taen from IPCo's 2006 IRP, pages 67 and 68. 31 Yanel, DI Irgators 1 A.Because of the newness of the program, similar data and calculations are not 2 available. The credit to be paid to participants in the new program wil be approximately $32 per 3 k W. Of course there wil be the cost of the equipment, installation costs and some level of 4 ongoing O&M. Collectively, these costs should be substantially below the $98 per kW benefit 5 that was calculated for a similar program for PacifiCorp. There wil be a large dollar benefit not 6 only for the Irrgators that paricipate, but for all customers on the system. 7 8 Q.HAS THE COMPANY'S PEAK REWARDS PROGRAM BENEFITED THE 9 IRRIGATORS, BY WAY OF THE COMPANY'S COST OF SERVICE STUDY IN THIS 10 CASE? 11 12 A.Yes. The interptibilty of the Irgators is reflected in this case. If there was an 13 interption at the time of any of the monthly peaks, there was an attempt to reflect the level of 14 that interption in the Company's cost of serice study. 15 16 Q.IS THE COMPANY'S METHOD OF FLOWING THROUGH THE LEVEL OF 17 INTERRUPTIONS INTO THE COST OF SERVICE STUDY IN THIS CASE 18 APPROPRIATE? 19 20 A.The treatment of the level of interptions in ths case, may have been appropriate 21 for now, but these methods wil probably need to be adjusted for the futue. Basically, the 22 problem faced by the Company is that for most classes it has load research meters that it uses to 23 gather data regarding what the peak contrbution to system peak is for customers within a given 32 Yanel, DI Irrgators 1 sample. The problem with the Irrgators is that the sample must not only represent the general 2 population, but it needs to represent the level of interrptions as well. Under the existing Peak 3 Rewards program there were a host of interption options and days during which an Irrgator 4 could be involved-all adding complexity. The Company's solution to this problem thus far has 5 been to pull out of the load research data any customers that may have been interrpted and then 6 determine the level of interptions from other data. 7 If there is a large level of parcipation as expected with the new program, the present 8 scheme may not work. Basically, such a large participation could wreak havoc on the load 9 research sample that was set up for other purposes. Additionally, the new program is not 10 designed for Irgation pumps less than 30 hp, which would mean that all of the interptible 11 customers would be in load research strata 2, 3, and 4, but not stratu 1. It is quite possible that 12 for such a large level of participation that the load research sample may need to be redesigned in 13 order to reflect two groups of customers-interptible and firm. 14 15 Q.WH IS IT IMPORTANT TO LOOK AT COST OF SERVICE RESULTS 16 FROM A PROGRAM THAT WILL NOT BE IMPLEMENTED UNTIL NEXT YEAR? 17 18 A.Rates set in this case will be implemented in the futue. Given the seasonality of 19 the Irrgation load, these rates wil be implemented for them at the same time as the new Peak 20 Rewards program wil be implemented. Normally, test year loads and costs are used as the basis 21 for setting future rates. However, "normally" implies that the past (test year) wil be a reflection 22 of the futue when rates are in effect. As was addressed above, "normally" does not properly 23 address the fact that the Irrgation load is not causing growt and the costs associated with that 33 Yanel, DI Irrgators 1 growth. Likewise, "normally" does not address the watershed change in Irrgation load that wil 2 take place under the new Peak Rewards program. 3 4 Q.WHAT WOULD BE THE IMPACT OF A 50% REDUCTION IN SYSTEM 5 PEAK CONTRIBUTION IN THIS CASE IF THE NEW PEAK REWARDS PROGRAM HAD 6 BEEN IN EFFECT FOR THE TEST YEAR? 7 8 A.The exact impact would be diffcult to calculate because there are a lot of 9 assumptions that would need to be made with respect to what impact the operation of this 10 new Peak Rewards program would have upon the overall system load. It would have 11 impacted the time and date of the monthly peaks-and the resulting class contrbutions to 12 those peaks as they var by day and hour of the day. For puroses of estimating the 13 impact of the new Peak Rewards program during the test year, I have simply assumed 14 that the Irgation peak contrbution is cut in half for the months of June and July (the 15 only two months when the new peak rewards program will be operating). 16 Exhibit 303 contains a summar page of the cost of service results under the 17 Company's base case and assuming that the Irgation peak contrbution to the June and 18 July system peaks were cut in half. As can be seen from Exhibit 303, the Irrgation rate 19 of retu has been increased from 3.36% in the Company's base case up to 5.12%, just 20 below the system average of 6.61 %. Exhibit 304 contains a similar sumar page that is 21 the cost of serice result based upon the same assumptions regarding the impact of the 22 Irrgation Peak Rewards program, but using the Company's new/preferred 3CP/12CP 34 Yanel, DI Irgators 1 cost of service study. As can be seen from Exhibit 304, the Irrgation rate of return has 2 been increased up to 6.19%, just below the system average of 6.61 %. 3 4 Q.HOW DO THE EXPECTED RESULTS OF THE COMPANY'S COST OF 5 SERVICE STUDIES REFLECT HOW COSTS SHOULD BE ALLOCATED TO THE 6 IRRIGATORS IN THIS CASE? 7 8 A.The Irrgation load is seasonal and thus, rates in this case for the Irrgators wil be 9 implemented next year-the same time that the new Peak Rewards program wil be 10 implemented. Rates for the Irrgators (like other classes) should be implemented in a maner 11 that reflects expectations at the time of implementation. The Irgation load wil be substantially 12 different in 2009 and rates should attempt to reflect that difference. Implementation of the new 13 Peak Rewards program wil essentially put the Irgators at the system average cost of servce 14 (absent any recogntion for the negative impact that the 25 years of disproportionate growth has 15 had on the Irrgators). Based simply on the adoption of the new Peak Rewards program (that 16 does not have to be anywhere near as successful as the results obtained for PacifiCorp), the 17 Irrgators should get no more than the system average rate increase. 35 Yanel, DI Irrgators ena:o 8 co89 N..c( M )- a:C) w a: coW ::z WW ()owz 0c( 0owz 0 c( c( ZQ. :: w- W eno :i01-W ZI- 0 :i ::C) w ii :: ~~ I- WZ :iwi- :: a:Q. 0 9 u. ~wo ~I: l' i.~§ .!2 Q) Q)l: en en- .. ~ ~ ~o ~ l'Q..- E Q) ~.¡: 21en e,l' 0).. :: ClgJ.5-'- 1: Itc( 0:::: ~l'l' ~"a ~.~ 8 Q) Q) Q)C) en ene ~!! ~ l' ~.~.~Q) Q) Q.C) en e li ~~.~¡:Q) Q) ~C) en () I:::.2Q. Õi~ 15 'CI- ~ "iI: ...- t/210l' ():: .s "Eo:: "i:;I:Q) ~ "a ..ëñ- & il "" co "" co M co co "" i( N ....~~~(OIlN~(tCOC'ui.. M N I' co "" I' co 0) .. N co ..~.. cD ~- a) 0 ('.. Ñ ci";CO il "".. il 0) co..""COCOIl"" 0) .. il M co il M "" 0) 0) "" 0)il "" 0) 0 0) 0) 0) N 0 0 N ""N co co co co "" .. 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N N O' c:en.- VI ü ::E Clei 0 enz r- CO CO 10 10 10 ol Cl r- .. r- Cl C/ ZIiÜ00~ ãl ãl l!00::....~ffff .s 8 ....ww ww o CO CO .~::o..Q)i:O 0 en ~ ,æNN..II Q)CD '- '-i: i:0 ~~ 1l..1l1l 0:::~~ .0 ..1l1l .! .!::en5II1I.c 1iEllEE ii ii .c :E l IIgj.c 1i~llEE .c .c ::~ e:¡:-Q) :-5i!0 ~ 8 - 0 i "E ::ii ~=t ~CJ ~5ao ~ ~- 0 Cl ClCli.-:: ::li.- ~~0 CQ)IIQ.IIC-::Q)UOQ)õ1i uu e 0 æQ)IIQ.II§:;::Q)uoQ)o êü::~LL::ci::~~cienozo I- 0:ci ci Cl ::0...LL::ci::....cienOzo I- 0: 2 - R E V E N U E R E Q U I R E M E N T S U M M A R Y - 10 T O T A L RA T E BA E 11 12 R E V E N U E S F R O M R A T E S 13 R E T A I L 14 15 T O T A L S A L E S R E V E N U E S 16 17 T O T A L O T H E R O P E R A T I N G R E V E N U E S 18 19 T O T A L R E V N U E S 20 21 O P E R A T I N G E X P E N S E S 22 W I T H O U T I N C T A X 23 24 O P E R A T I N G I N C O M E 25 B E F O R E I N C O M E T A X E S 26 27 T O T A L F E D E R A L I N C O M E T A X 28 T O T A L S T A T E I N C O M E T A X 29 30 T O T A L O P E R A T I N G E X P E N S E S 31 32 T O T A L O P E R A T I N G I N C O M E 33 34 A D D : I E R C O O P E R A T I N G I N C O M E 35 C O N S O L I D A T E D O P E R I N C O M E 36 37 R A T E S O F R E T U R N 38 R A T E S O F R E T U R N - I N D E X 39 A V E R A G E M I L L S I K 40 41 R E V E N U E R E Q U I R E M E N T C A L C U L A T I N 42 R A T E O F R E T U R N R E Q U I R E D 43 44 R E Q U I R E D R E V E N U E 45 R E V E N U E D E F I C I E N C Y 46 P E R C E N T C H A N G E R E Q U I R E D 47 R E T U R N A T C L A I M E D R O R 48 E A R N I N G S D E F I C I E N C Y 49 50 R E V E N U E R E Q U I R E M E N T F O R A T E D E S I G N 51 T O T A L I D A H S A L E S R E V E N U E S 52 53 R E Q U E S T E D C H A N G E I N R E V E N U E ( % ) (A ) SO U R C E S &~ T O T A L (B ) RE S I D E N T I A L 2, 0 9 3 , 3 9 8 , 8 5 9 9 4 1 , 0 2 0 , 2 9 9 (1 ) 67 3 , 1 6 9 , 5 4 0 3 1 7 , 9 5 6 , 4 6 1 67 3 , 1 6 9 , 5 4 3 1 7 , 9 5 6 , 4 6 1 13 6 , 7 2 2 , 4 4 3 5 0 , 1 8 4 , 3 0 2 80 9 , 8 9 1 , 9 8 3 3 6 8 , 1 4 0 , 7 6 3 66 2 , 5 3 1 , 2 8 2 2 8 2 , 0 1 9 , 7 4 1 14 7 , 3 6 0 , 7 0 0 8 6 , 1 2 1 , 0 2 2 19 , 0 6 2 , 4 3 9 (3 , 6 6 1 , 4 7 9 ) 67 7 , 9 3 2 , 2 4 3 13 1 , 9 5 9 , 7 4 0 E1 ( 6,4 7 2 , 7 0 3 13 8 , 4 3 2 , 4 4 3 73 9 , 7 5 7 , 8 2 7 66 , 5 8 8 , 2 8 7 9. 8 9 % 17 8 , 9 8 5 , 6 0 2 40 , 5 5 3 , 1 5 9 8, 5 6 8 , 9 0 8 (1 , 6 4 5 , 9 0 1 ) 28 8 , 9 4 2 , 7 4 8 79 , 1 9 8 , 0 1 5 2, 2 8 7 , 9 5 9 81 , 4 8 5 , 9 7 4 6. 6 1 3 1.0 0 0 53 . 7 2 8. 5 5 0 31 6 , 2 6 7 , 2 7 2 (1 , 6 8 9 , 1 8 9 ) -0 . 5 3 % 80 , 4 5 7 , 2 3 6 (1 , 0 2 8 , 7 3 9 ) (C ) GE N S R V (7 ) II P A G r o w t h W e i g h t e d BA S E C A S E C L A S S C O S T O F S E R V I C E S T U D Y TW E L V E M O N T H S E N D I N G D E C E M B E R 3 1 , 2 0 0 8 (D ) GE N S R V PR I M A R Y (9 . P ) (E ) GE N S R V SE C O N D A R Y (9 - 5 ) 49 , 5 0 9 , 9 2 2 6 3 , 3 2 1 , 2 6 6 5 4 2 , 2 3 6 , 7 0 5 15 , 1 6 1 , 3 7 9 1 5 , 5 3 5 , 0 8 9 1 4 1 , 9 0 9 , 1 7 6 15 , 1 6 1 , 3 7 9 1 5 , 5 3 5 , 0 8 9 1 4 1 , 9 0 9 , 1 7 6 2, 7 4 4 , 4 0 4 6 , 5 7 3 , 0 0 0 4 1 , 6 5 6 , 0 4 17 , 9 0 5 , 7 8 3 2 2 , 1 0 8 , 0 8 9 1 8 3 , 5 6 5 , 2 2 0 16 , 8 3 9 , 1 3 1 2 2 , 4 1 1 , 9 9 4 1 8 7 , 9 7 3 , 9 1 4 1, 0 6 6 , 6 5 2 ( 3 0 3 , 9 0 5 ) ( 4 , 4 0 8 , 6 9 3 ) 45 0 , 8 3 6 (8 6 , 5 9 6 ) 17 , 2 0 3 , 3 7 2 70 2 , 4 1 1 13 2 , 2 4 7 83 4 , 6 5 8 8. 6 5 9 1.3 0 9 62 . 7 7 8. 5 5 0 20 , 7 4 1 , 6 1 8 5, 5 8 0 , 2 3 9 36 . 8 1 % 4, 2 3 3 , 0 9 8 3, 3 9 8 , 4 0 57 6 , 6 0 2 (1 1 0 , 7 5 3 ) 22 , 8 7 7 , 8 4 (7 6 9 , 7 5 5 ) 27 2 , 8 5 0 (4 9 6 , 9 0 4 ) 1.6 8 6 0. 2 5 5 79 . 5 5 8. 5 5 25 , 2 4 0 , 7 4 2 9, 7 0 5 , 6 5 3 62 . 4 8 % 5, 4 1 3 , 9 6 8 5, 9 1 0 , 8 7 3 4, 9 3 7 , 5 9 4 (9 4 8 , 4 0 4 ) 19 1 , 9 6 3 , 1 0 4 (8 , 3 9 7 , 8 8 3 ) 2, 2 0 5 , 1 5 5 (6 , 1 9 2 , 7 2 8 ) -0 . 7 8 5 -0 . 1 1 9 37 . 8 6 -1 . 1 4 2 -0 . 1 7 3 44 . 4 7 8.5 5 0 8. 5 5 0 22 8 , 2 0 2 , 7 8 8 86 , 2 9 3 , 6 1 2 60 . 8 1 % 46 , 3 6 1 , 2 3 8 52 , 5 5 3 , 9 6 6 67 3 , 1 6 9 , 5 4 0 3 1 7 , 9 5 6 , 4 6 1 1 5 , 1 6 1 , 3 7 9 1 5 , 5 3 5 , 0 8 9 1 4 1 , 9 0 9 , 1 7 6 9. 8 9 % - 0 . 5 3 % 3 6 . 8 1 % 6 2 . 4 8 % 6 0 . 8 1 % (F ) AR E A LIG H T I N G (1 5 ) (G ) LG P O W E R PR I M A R Y (1 9 . P ) (H ) ( I ) ( J ) IR R I G A T I O N U N M E T E R E D M U N I C I P A L SE C O N D A R Y G E N S E R V I C E S T L I G H T (2 4 - 5 ) ( 4 0 ) ( 4 1 ) 1, 0 4 7 , 6 9 8 2 6 6 , 9 7 4 , 2 0 2 1 6 4 , 9 0 8 , 4 3 4 1, 0 0 4 , 5 0 8 7 0 , 2 7 1 , 1 0 6 7 7 , 0 4 5 , 5 7 4 1, 0 0 4 , 5 0 8 7 0 , 2 7 1 , 1 0 6 7 7 , 0 4 5 , 5 7 4 16 7 , 9 4 6 2 7 , 5 0 2 , 4 8 8 2 , 2 1 9 , 1 5 2 1, 1 7 2 , 4 5 4 9 7 , 7 7 3 , 5 9 4 7 9 , 2 6 4 , 7 2 6 90 8 , 7 5 5 1 0 0 , 8 1 6 , 4 3 7 2 8 , 2 0 8 , 4 5 5 26 3 , 7 0 0 ( 3 , 0 4 2 , 8 4 4 ) 5 1 , 0 5 6 , 2 7 1 91 6 , 4 6 3 25 5 , 9 9 2 4, 0 6 8 26 0 , 0 6 0 24 . 8 2 2 3. 7 5 4 16 8 . 2 72 4 , 5 7 7 (2 7 9 , 9 3 1 ) -2 7 . 8 7 % 89 , 5 7 8 (1 7 0 , 4 8 2 ) 9, 5 4 (1 , 8 3 2 ) 2,4 3 1 , 0 6 1 (4 6 6 , 9 5 4 ) 1, 5 0 1 , 6 5 2 (2 8 8 , 3 5 ) 29 , 4 2 1 , 6 7 3 49 , 8 4 3 , 0 5 3 37 , 8 9 9 49 , 8 8 0 , 9 5 2 .1 . 3 9 6 -0 . 2 1 1 33 . 0 9 30 . 2 4 8 4. 5 7 4 49 . 6 6 10 2 , 7 8 0 , 5 4 (5 , 0 0 6 , 9 5 0 ) 1, 2 7 9 , 1 7 4 (3 , 7 2 7 , 7 7 6 ) 8. 5 5 0 11 3 , 8 7 2 , 8 8 9 43 , 6 0 1 , 7 8 3 62 . 0 5 % 22 , 8 2 6 , 2 9 4 26 , 5 5 4 , 0 7 0 8. 5 5 0 18 , 2 9 2 , 7 1 1 (5 8 , 7 5 2 , 8 6 3 ) -7 6 . 2 6 % 14 , 0 9 9 , 6 7 1 (3 5 , 7 8 1 , 2 8 1 ) 1, 0 0 4 , 5 0 8 7 0 , 2 7 1 , 1 0 6 7 7 , 0 4 5 , 5 7 4 .2 7 . 8 7 % 6 2 . 0 5 % - 7 6 . 2 6 % 3,2 1 8 , 4 4 96 6 , 4 9 1 96 6 , 4 9 1 21 5 , 1 8 5 1,1 8 1 , 6 7 6 1,1 1 1 , 1 8 3 70 , 4 9 2 29 , 3 0 7 (5 , 6 2 9 ) 1, 1 3 4 , 8 6 1 46 , 8 1 5 11 , 4 3 6 58 , 2 5 1 1.8 1 0 0. 2 7 4 57 . 7 4 8. 5 5 0 1, 3 2 2 , 6 8 5 35 6 , 1 9 4 36 . 8 5 % 27 5 , 1 7 7 21 6 , 9 2 7 96 6 , 4 9 1 36 . 8 5 % 3, 7 7 5 , 9 0 2, 3 1 4 , 2 6 1 2, 3 1 4 , 2 6 1 44 8 , 2 9 1 2,7 6 2 , 5 5 2 2, 2 9 1 , 7 3 0 47 0 , 8 2 3 34 , 3 8 3 (6 , 6 0 4 ) 2, 3 1 9 , 5 0 9 44 , 0 4 15 , 0 9 7 45 8 , 1 4 1 12 . 1 3 3 1.8 3 5 10 4 . 7 9 8. 5 5 0 2, 0 9 2 , 0 9 6 (2 2 2 , 1 6 5 ) .9 . 6 0 % 32 2 , 8 3 9 (1 3 5 , 3 0 1 ) 2,3 1 4 , 2 6 1 .9 . 6 0 % (K ) TR A F I C CO N T R O L (4 2 ) (L ) SC DO E l I N L (M ) SC JR S I M P L O T (N ) SC MI C R O N 64 7 , 8 4 6 1 0 , 4 7 5 , 7 5 6 1 1 , 9 6 2 , 4 3 2 3 4 , 2 9 9 , 9 5 2 15 5 , 2 0 3 5 , 8 2 8 , 1 7 5 5 , 0 1 8 , 1 5 9 2 0 , 0 0 3 , 9 5 8 15 5 , 2 0 3 5 , 8 2 8 , 1 7 5 5 , 0 1 8 , 1 5 9 2 0 , 0 0 3 , 9 5 8 54 , 3 7 3 8 5 3 , 6 3 2 1 , 2 8 3 , 3 2 1 2 , 8 2 0 , 3 0 4 20 9 , 5 7 6 6 , 6 8 1 , 8 0 7 6 , 3 0 1 , 4 8 0 2 2 , 8 2 4 , 2 6 2 24 4 , 3 6 5 3 , 5 6 8 , 4 4 2 3 , 4 2 2 , 5 7 6 1 2 , 7 1 4 , 5 5 9 (3 4 , 7 8 9 ) 3 , 1 1 3 , 3 6 5 2 , 8 7 8 , 9 0 4 1 0 , 1 0 9 , 7 0 3 24 9 , 1 3 1 (3 9 , 5 5 5 ) 2, 8 6 2 (3 6 , 6 9 3 ) .5 . 6 6 4 -0 . 8 5 6 36 . 8 9 8. 5 5 0 30 6 , 4 0 4 15 1 , 2 0 1 97 . 4 2 % 55 , 3 9 1 92 , 0 8 4 5,8 9 9 (1 , 1 3 3 ) 95 , 3 9 2 (1 8 , 3 2 3 ) 10 8 , 9 3 0 (2 0 , 9 2 3 ) 3, 5 1 0 , 5 8 2 2, 7 9 0 , 8 9 8 38 , 6 7 6 2, 8 2 9 , 5 7 4 29 . 3 9 3 4. 4 4 5 27 . 1 1 23 . 6 5 4 3. 5 7 7 26 . 4 31 2 , 3 3 5 (5 9 , 9 9 3 ) 12 , 9 6 6 , 9 0 1 9, 8 5 7 , 3 6 1 14 2 , 4 5 1 9, 9 9 9 , 8 1 2 29 . 1 5 4 4.4 0 9 28 . 4 4 8. 5 5 0 8. 5 5 0 3, 6 4 5 , 5 1 1 3, 0 3 6 , 2 9 5 42 , 8 2 7 3, 0 7 9 , 1 2 3 8. 5 5 0 2,2 4 2 , 9 5 7 (3 , 5 8 5 , 2 1 8 ) -6 1 . 5 2 % 89 5 , 6 7 7 (2 , 1 8 3 , 4 4 ) 8. 5 5 0 .5 9 . 1 2 % 2, 0 5 1 , 4 1 7 8 , 3 9 9 , 6 7 1 (2 , 9 6 6 , 7 4 2 ) ( 1 1 , 6 0 4 , 2 8 7 ) .5 8 . 0 1 % 1, 0 2 2 , 7 8 8 (1 , 8 0 6 , 7 8 6 ) 2, 9 3 2 , 6 4 6 (7 , 0 6 7 , 1 6 6 ) 15 5 , 2 0 3 5 , 8 2 8 , 1 7 5 5 , 0 1 8 , 1 5 9 2 0 , 0 0 3 , 9 5 8 97 . 4 2 % - 6 1 , 5 2 % . 5 9 . 1 2 % . 5 8 . 0 1 % Ex h i b i t 30 2 - R E V N U E R E Q U I R E M E N T S U M M A R Y - 10 T O T A L R A T E B A S E 11 12 R E V E N U E S F R O M R A T E S 13 R E T A I L 14 15 T O T A L S A L E S R E V E N U E S 16 17 T O T A L O T H E R O P E R A T I N G R E V E N U E S 18 19 T O T A L R E V E N U E S 21 O P E R A T I N G E X P E N S E S 22 W I T H O U T I N C T A X 23 24 O P E R A T I N G I N C O M E 25 B E F O R E I N C O M E T A X E S 26 27 T O T A L F E D E R A I N C O M E T A X 28 T O T A L S T A T E I N C O M E T A X 29 30 T O T A L O P E R A T I N G E X P E N S E S 31 32 T O T A L O P E R A T I N G I N C O M E 33 34 A D D : I E R C O O P E R A T I N G I N C O M E 35 C O N S O L I D A T E D O P E R I N C O M E 36 37 R A T E S O F R E T U R N 38 R A T E S O F R E T U R N . IN D E X 39 A V E R A G E M I L L S I K W H 40 41 R E V E N U E R E Q U I R E M E N T C A L C U L A T I O N 42 R A T E O F R E T U R N R E Q U I R E D 43 44 R E Q U I R E D R E V E N U E 45 R E V E N U E D E F I C I E N C Y 46 P E R C E N T C H A N G E R E Q U I R E D 47 R E T U R N A T C L A I M E D R O R 48 E A R N I N G S D E F I C I E N C Y 49 50 R E V E N U E R E Q U I R E M E N T F O R R A T E D E S I G N 51 T O T A L I D A H O S A L E S R E V E N U E S 52 53 R E Q U E S T E D C H A N G E I N R E V E N U E ( % ) (A ) TO T A L 2, 0 9 3 , 3 9 8 , 8 5 9 67 3 , 1 6 9 , 5 4 0 67 3 , 1 8 9 , 5 4 0 13 6 , 7 2 2 , 4 4 3 80 9 , 8 9 1 , 9 8 3 66 2 , 5 3 1 , 2 8 2 14 7 , 3 6 , 7 0 0 19 , 0 6 2 , 4 3 9 (3 , 6 6 1 , 4 7 9 ) 67 7 , 9 3 2 , 2 4 3 13 1 , 9 5 9 , 7 4 0 6,4 7 2 , 7 0 3 13 6 , 4 3 2 , 4 4 3 73 9 , 7 5 7 , 8 2 7 66 , 5 8 9 , 2 8 7 9.8 9 % 17 8 , 9 8 5 , 6 0 2 40 , 5 5 3 , 1 5 9 67 3 , 1 6 9 , 5 4 0 (B ) RE S I D E N T I A l (1 ) 95 8 , 8 7 6 , 9 7 1 31 7 , 9 5 6 , 4 6 1 31 7 , 9 5 8 , 4 6 1 52 , 7 8 5 , 6 1 9 37 0 , 7 4 2 , 0 6 0 29 0 , 9 4 0 , 6 0 1 79 , 8 0 1 , 4 7 9 8, 7 3 1 , 5 1 1 (1 , 6 7 7 , 1 3 3 ) 29 7 , 9 9 , 9 7 9 72 , 7 4 7 , 1 0 2 2, 4 3 0 , 5 0 0 75 , 1 7 7 , 6 0 2 6.6 1 3 1.0 0 0 53 . 7 2 7. 8 4 0 1. 1 8 6 62 . 7 7 8.5 5 0 8. 5 5 0 32 9 , 1 3 2 , 5 3 6 11 , 1 7 6 , 0 7 5 3.5 1 % 81 , 9 8 3 , 9 8 1 6, 8 0 6 , 3 7 9 31 7 , 9 5 8 , 4 6 1 9.8 9 % 3.5 1 % (C ) GE N S R V (7 ) 43 , 4 9 4 , 8 2 9 15 , 1 6 1 , 3 7 9 15 , 1 6 1 , 3 7 9 2, 0 1 7 , 6 4 2 17 , 1 7 9 , 0 2 1 14 , 0 3 9 , 7 6 0 3,1 3 9 , 2 6 0 39 6 , 0 6 3 (7 6 , 0 7 5 ) 14 , 3 5 9 , 7 4 8 2,8 1 9 , 2 7 3 91 , 2 6 5 2,9 1 0 , 5 3 8 6.6 9 2 1.0 1 2 79 . 5 5 8.5 5 0 16 , 4 8 8 , 5 5 9 1,3 2 7 , 1 6 0 8. 7 5 % 3,7 1 8 , 8 0 8 80 8 , 2 7 0 15 , 1 6 1 , 3 7 9 8. 7 5 % II P A 5 0 % P e a k v a l u e J u n e a n d J u l y IP C o ' s B A S E C A S E C L A S S C O S T O F S E R V I C E S T U D Y TW E L V E M O N T H S E N D I N G D E C E M B E R 3 1 , 2 0 0 8 (D ) GE N S R V PR I M A R Y (9 - P ) 51 , 3 9 2 , 5 1 8 15 , 5 3 5 , 0 8 9 15 , 5 3 5 , 0 8 9 5, 0 7 2 , 2 4 6 20 , 6 0 7 , 3 3 5 16 , 6 8 8 , 1 9 1 3, 9 1 9 , 1 4 4 46 7 , 9 7 9 (8 9 , 8 8 9 ) 17 , 0 6 8 , 2 8 2 3, 5 4 1 , 0 5 3 18 7 , 7 0 8 3, 7 2 8 , 7 6 2 16 , 6 2 7 , 5 0 9 1, 0 9 2 , 4 2 0 7.0 3 % 4, 3 9 4 , 0 6 66 5 , 2 9 9 15 , 5 3 5 , 8 9 (E ) GE N S R V SE C O N D A R Y (9 - S ) 44 4 , 0 6 4 , 3 2 7 14 1 , 9 0 9 , 1 7 6 14 1 , 9 0 9 , 1 7 6 29 , 4 9 4 , 9 2 2 17 1 , 4 0 4 , 0 9 8 14 1 , 3 9 8 , 8 9 7 30 , 0 0 7 , 2 0 0 4,0 4 3 , 6 3 9 (7 7 6 , 6 9 5 ) 14 4 , 6 6 3 , 8 4 2 26 , 7 4 0 , 2 5 8 1,5 1 6 , 5 5 4 28 , 2 5 8 , 8 1 0 7. 2 5 5 1. 0 9 7 37 . 8 6 8. 5 5 0 15 7 , 8 5 4 , 1 2 8 15 , 9 4 4 , 9 5 2 11 . 2 4 % 37 , 9 6 7 , 5 0 0 9, 7 1 0 , 6 9 0 14 1 , 9 0 9 , 1 7 6 7.0 3 % 11 . 2 4 % (F ) AR E A LI G H T I N G (1 5 ) 92 5 , 0 2 7 1,0 0 4 , 5 0 8 1,0 0 4 , 5 0 8 14 3 , 9 7 8 1, 1 4 8 , 4 8 6 82 1 , 0 9 6 32 7 , 3 9 0 8, 4 2 3 (1 , 6 1 8 ) 82 7 , 9 0 2 32 0 , 5 8 5 2, 5 8 9 32 3 , 1 7 4 6. 3 6 3 0. 9 6 2 44 . 4 7 34 . 9 3 7 5. 2 8 3 16 8 . 6 2 8. 5 5 0 8.5 5 0 60 3 , 7 2 2 (4 0 0 , 7 8 6 ) -3 9 . 9 0 % 79 , 0 9 0 (2 4 4 , 0 8 4 ) 1, 0 0 4 , 5 0 8 .3 9 . 9 0 % (G ) LG P O W E R PR I M A R Y (1 9 - P ) 22 6 , 9 0 2 , 4 5 7 70 , 2 7 1 , 1 0 6 70 , 2 7 1 , 1 0 6 22 , 1 0 3 , 2 0 6 92 , 3 7 4 , 3 1 2 80 , 5 8 3 , 9 8 11 , 7 9 0 , 3 3 1 2,0 6 8 , 1 6 8 (3 9 6 , 8 8 6 ) 82 , 2 5 3 , 2 8 3 10 , 1 2 1 , 0 2 9 97 0 , 2 5 8 11 , 0 9 1 , 2 8 7 83 , 9 1 4 , 2 7 6 13 , 6 4 3 , 1 7 0 19 . 4 2 % 19 , 4 0 0 , 1 6 0 8, 3 0 , 8 7 3 70 , 2 7 1 , 1 0 6 19 . 4 2 % (H ) IR R I G A T I O N SE C O N D A R Y (2 4 - S ) 26 6 , 7 4 2 , 9 8 9 77 , 0 4 5 , 5 7 4 77 , 0 4 5 , 5 7 4 14 , 8 7 5 , 7 7 8 91 , 9 2 1 , 3 5 2 77 , 0 6 5 , 3 1 7 14 , 8 5 6 , 0 3 5 2, 4 2 8 , 9 5 5 (4 6 6 , 5 4 9 ) 79 , 0 2 7 , 7 2 3 12 , 8 9 3 , 6 2 9 75 9 , 8 9 5 13 , 6 5 3 , 5 2 4 4.8 8 8 0.7 3 9 33 . 0 9 5. 1 1 9 0.7 7 4 49 . 6 8 8.5 5 0 8.5 5 0 92 , 0 7 4 , 8 0 2 15 , 0 2 9 , 2 2 8 19 . 5 1 % 22 , 8 0 6 , 5 2 6 9,1 5 3 , 0 0 1 77 , 0 4 5 , 5 7 4 19 . 5 1 % (I ) UN M E T E R E D GE N S E R V I C E (4 0 ) 2, 7 5 2 , 0 9 9 96 6 , 4 9 1 96 6 , 4 9 1 15 1 , 2 7 5 1,1 1 7 , 7 6 6 87 2 , 2 9 4 24 5 , 4 7 1 25 , 0 6 1 (4 , 8 1 4 ) 89 2 , 5 4 1 22 5 , 2 2 4 7,7 6 7 23 2 , 9 9 2 97 0 , 2 8 9 3, 7 9 8 0. 3 9 % 23 5 , 3 0 4 2, 3 1 3 96 6 , 4 9 1 (J ) MU N I C I P A L ST L I G H T (4 1 ) 3, 2 7 7 , 0 8 3 2,3 1 4 , 2 6 1 2, 3 1 4 , 2 6 1 36 6 , 1 5 4 2, 6 8 0 , 4 1 5 2, 0 0 3 , 0 4 3 67 7 , 3 7 1 29 , 8 4 1 (5 , 7 3 2 ) 2, 0 2 7 , 1 5 2 65 3 , 2 6 2 10 , 3 5 66 3 , 8 1 9 8. 4 6 6 1.2 8 0 57 . 7 4 20 . 2 5 0 3. 0 6 2 10 4 . 7 9 8. 5 5 0 8. 5 5 0 1, 6 8 , 6 7 2 (8 2 9 , 5 8 9 ) -2 7 . 2 0 % 28 0 , 1 9 1 (3 8 , 4 2 8 ) 2,3 1 4 , 2 6 1 0.3 9 % -2 7 . 2 0 % (K ) TR A F F I C CO N T R O L (4 2 ) 50 9 , 2 6 3 15 5 , 2 0 3 15 5 , 2 0 3 37 , 9 1 7 19 3 , 1 2 0 18 1 , 1 3 1 11 , 9 8 9 18 4 , 8 7 7 1,9 4 2 10 , 1 8 4 20 9 , 9 7 7 54 , 7 7 4 35 . 2 9 % 43 , 5 4 2 33 , 3 5 8 15 5 , 2 0 3 35 . 2 9 % (L ) SC DO E / l N L 17 , 6 4 1 , 0 0 8 5, 8 2 8 , 1 7 5 5,8 2 8 , 1 7 5 1, 7 5 7 , 5 5 3 7,5 8 5 , 7 2 8 7, 0 4 5 , 0 9 6 54 0 , 6 3 1 4, 6 3 7 (8 9 1 ) 16 0 , 6 3 9 (3 0 , 8 5 5 ) 7,1 7 4 , 8 8 0 8,2 4 2 41 0 , 8 4 8 94 , 5 0 1 50 5 , 3 4 9 2. 0 0 0 0. 3 0 2 36 . 8 9 8. 5 5 0 7, 4 7 5 , 0 3 0 1, 6 4 6 , 8 5 5 28 . 2 6 % 1, 5 0 8 , 3 0 6 1, 0 0 2 , 9 5 7 5,8 2 8 , 1 7 5 28 . 2 6 % (M ) SC JR S I M P L O T (N ) SC MI C R O N 18 , 3 8 3 , 8 3 9 5 8 , 4 3 6 , 4 4 9 5,0 1 8 , 1 5 9 5, 0 1 8 , 1 5 9 2 0 , 0 0 3 , 9 5 8 20 , 0 0 3 , 9 5 8 2,0 9 8 , 5 4 4 7,1 1 6 , 7 0 3 6, 5 8 3 , 3 2 2 55 , 3 8 1 16 7 , 4 0 3 (3 2 , 1 5 4 ) 6, 6 9 8 , 5 7 0 41 8 , 1 3 3 85 , 4 4 0 50 3 , 5 7 3 2. 8 6 5 0. 4 3 3 27 . 1 1 8. 5 5 0 6,7 7 2 , 2 1 9 1,7 5 4 , 0 6 34 . 9 5 % 1, 5 7 1 , 8 1 8 1, 0 6 8 , 2 4 6 5, 0 1 8 , 1 5 9 34 . 9 5 % Ex h i b i t 3 0 3 5,8 1 7 , 6 1 0 25 , 8 2 1 , 5 6 8 24 , 3 3 0 , 5 5 1 1, 4 9 1 , 0 1 7 53 2 , 1 2 1 (1 0 2 , 2 0 9 ) 24 , 7 6 0 , 4 6 3 1,0 6 1 , 1 0 5 31 3 , 9 2 6 1,3 7 5 , 0 3 1 2. 7 3 9 0.4 1 4 26 . 4 7 2. 3 5 3 0. 3 5 6 28 . 4 4 8. 5 5 8.5 5 0 25 , 9 5 0 , 1 0 9 5,9 4 6 , 1 5 1 29 . 7 2 % 4, 9 9 , 3 1 6 3,6 2 1 , 2 8 6 20 , 0 0 3 , 9 5 8 29 . 7 2 % - R E V E N U E R E Q U I R E M E N T S U M M A R Y - 6 10 T O T A L R A T E B A E 11 12 R E V E N U E S F R O M R A T E S 13 R E T A I L 14 15 T O T A L S A L E S R E V E N U E S 16 17 T O T A L O T H E R O P E R A T I N G R E V E N U E S 18 19 T O T A L R E V E N U E S 20 21 O P E R A T I N G E X E N S E S 22 W I T H O U T I N C T A X 23 24 O P E R A T I N G I N C O M E 25 B E F O R E I N C O M E T A X E S 26 27 T O T A L F E D E R A I N C O M E T A X 28 T O T A L S T A T E I N C O M E T A X 29 30 T O T A L O P E R A T I N G E X P E N S E S 31 32 T O T A L O P E R A T I N G I N C O M E 33 34 A D D : I E R C O O P E R A T I N G I N C O M E 35 C O N S O L I D A T E D O P E R I N C O M E 36 37 R A T E S O F R E T U R N 38 R A T E S O F R E T U R N . IN D E X 39 A V E R A G E M I L L S I K 40 41 R E V E N U E R E Q U I R E M E N T C A L C U L A T I O N 42 R A T E O F R E T U R N R E Q U I R E D 43 44 R E Q U I R E D R E V E N U E 45 R E V E N U E D E F I C I E N C Y 46 P E R C E N T C H A G E R E Q U I R E D 47 R E T U R N A T C L A I M E D R O R 48 E A R N I N G S D E F I C I E N C Y 49 50 R E V N U E R E Q U I R E M E N T F O R R A T E D E S I G N 51 T O T A L I D A H O S A L E S R E V E N U E S 52 53 R E Q U E S T E D C H A N G E I N R E V E N U E ( % ) (A ) TO T A L 2,0 9 3 , 3 9 8 , 8 5 9 67 3 , 1 6 9 , 5 4 67 3 , 1 6 9 , 5 4 0 13 6 , 7 2 2 , 4 4 80 9 , 8 9 1 , 9 8 3 66 2 , 5 3 1 , 2 8 2 14 7 , 3 6 0 , 7 0 0 19 , 0 6 2 , 4 3 9 (3 , 6 6 1 , 4 7 9 ) 67 7 , 9 3 2 , 2 4 3 13 1 , 9 5 9 , 7 4 0 6,4 7 2 , 7 0 3 13 6 , 4 3 2 , 4 4 3 73 9 , 7 5 7 , 8 2 7 66 , 5 8 8 , 2 8 7 9.8 9 % 17 8 , 9 8 5 , 6 0 2 40 , 5 5 3 , 1 5 9 67 3 , 1 6 9 , 5 4 0 (B ) RE S I D E N T I A L (1 ) 96 0 , 4 3 9 , 2 1 7 31 7 , 9 5 6 , 4 6 1 31 7 , 9 5 6 , 4 6 1 52 , 7 4 3 , 8 9 6 37 0 , 7 0 0 , 3 5 7 29 4 , 6 0 8 , 0 5 4 76 , 0 9 2 , 3 0 2 8, 7 4 5 , 7 3 6 (1 , 6 7 9 , 8 6 5 ) 30 1 , 6 7 3 , 9 2 5 69 , 0 2 6 , 4 3 2 2, 4 2 6 , 6 1 6 71 , 4 5 3 , 0 4 8 6.6 1 3 1. 0 0 0 53 . 7 2 7. 4 4 1. 1 2 5 62 . 7 7 8.5 5 0 8. 5 5 0 33 5 , 4 6 7 , 5 7 8 17 , 5 1 1 , 1 1 7 5. 5 1 % 82 , 1 1 7 , 5 5 3 10 , 6 6 4 , 5 0 5 31 7 , 9 5 6 , 4 6 1 9.8 9 % 5. 5 1 % (C ) GE N S R V (7 ) 43 , 5 8 0 , 3 3 1 15 , 1 6 1 , 3 7 9 15 , 1 6 1 , 3 7 9 2,0 1 7 , 3 9 1 17 , 1 7 8 , 7 7 0 14 , 0 7 5 , 7 7 5 3,1 0 2 , 9 9 5 39 6 , 8 4 1 (7 6 , 2 2 5 ) 14 , 3 9 6 , 3 9 2 2, 7 8 2 , 3 7 8 91 , 2 6 5 2, 8 7 3 , 6 4 3 6. 5 9 4 0. 9 9 7 79 . 5 5 8. 5 5 0 16 , 5 6 1 , 1 4 4 1,3 9 9 , 7 6 5 9. 2 3 % 3, n 6 , l 1 8 85 2 , 4 7 5 15 , 1 6 1 , 3 7 9 9. 2 3 % IIP A 5 0 % P e a k v a l u e J u n e a n d J u l y IP C o ' s 3 C P / 1 2 C P C L A S S C O S T O F S E R V I C E S T U D Y TW E L V E M O N T H S E N D I N G D E C E M B E R 3 1 , 2 0 0 8 (D ) GE N S R V PR I M A R Y (9 - P ) 51 , 5 2 8 , 0 0 1 15 , 5 3 5 , 0 8 9 15 , 5 3 5 , 0 8 9 5,0 8 3 , 5 0 3 20 , 6 1 8 , 5 9 2 16 , 6 9 2 , 6 7 4 3,9 2 5 , 9 1 7 46 9 , 2 1 3 (9 0 , 1 2 6 ) 17 , 0 7 1 , 7 6 2 3, 5 4 , 8 3 0 18 8 , 3 5 6 3,7 3 5 , 1 8 6 16 , 6 3 5 , 9 8 1 1, 1 0 0 , 8 9 2 4, 4 0 5 , 6 4 67 0 , 4 5 8 15 , 5 3 5 , 0 8 9 (E ) GE N S R V SE C O N D A R Y (9 - 5 ) 44 4 , 5 5 4 , 1 2 9 14 1 , 9 0 9 , 1 7 6 14 1 , 9 0 9 , 1 7 6 29 , 5 7 0 , 2 1 8 17 1 , 4 7 9 , 3 9 4 14 1 , 4 8 0 , 8 7 9 29 , 9 9 8 , 5 1 5 4, 0 4 8 , 9 9 (7 7 7 , 5 5 2 ) 14 4 , 7 5 1 , 4 2 6 26 , 7 2 7 , 9 6 7 1, 5 2 1 , 0 8 5 28 , 2 4 9 , 0 5 3 7.2 4 9 1.0 9 6 37 . 8 6 6.3 5 4 0. 9 6 1 44 . 4 7 8.5 5 0 8. 5 5 0 7. 0 9 % 15 7 , 9 3 5 , 6 3 0 16 , 0 2 6 , 4 5 4 11 . 2 9 % 36 , 0 0 9 , 3 7 8 9,7 6 0 , 3 2 5 14 1 , 9 0 9 , 1 7 6 7. 0 9 % 11 . 2 9 % (F ) AR E A LI G H T I N G (1 5 ) 91 6 , 3 2 7 1, 0 0 , 5 0 8 1, 0 0 4 , 5 0 8 14 3 , 2 5 2 1, 1 4 7 , 7 6 0 81 2 , 7 1 4 33 5 , 0 4 6 8, 3 4 (1 , 6 0 3 ) 81 9 , 4 5 5 32 8 , 3 0 4 2, 5 8 9 33 0 , 8 9 3 36 . 1 1 1 5.4 6 1 16 8 . 2 8.5 5 0 58 9 , 8 2 5 (4 1 4 , 6 8 3 ) -4 1 . 2 8 % 78 , 3 4 (2 5 2 , 5 4 8 ) 1, 0 0 4 , 5 0 8 -4 1 . 2 8 % (G ) LG P O W E R PR I M A R Y (1 9 . P ) 22 7 , 5 8 4 , 7 4 8 70 , 2 7 1 , 1 0 6 70 , 2 7 1 , 1 0 6 22 , 1 9 6 , 4 2 3 92 , 4 6 7 , 5 2 9 80 , 1 3 9 , 9 7 8 12 , 3 2 7 , 5 5 1 2, o n , 3 6 1 (3 9 8 , 0 5 9 ) 81 , 8 1 4 , 2 9 9 10 , 6 5 3 , 2 2 9 97 6 , 0 8 4 11 , 6 2 9 , 3 1 3 83 , 1 2 6 , 6 2 5 12 , 8 5 5 , 5 1 9 18 . 2 9 % 19 , 4 5 8 , 9 6 7, 8 2 9 , 1 8 3 70 , 2 7 1 , 1 0 6 18 . 2 9 % (H ) ( I ) IR R I G A T I O N U N M E T E R E D SE C O N D A R Y G E N S E R V I C E (2 4 - ) ( 4 0 ) 26 3 , 3 6 0 , 7 6 9 77 , 0 4 5 , 5 7 4 77 , 0 4 5 , 5 7 4 14 , 6 9 5 , 2 0 7 91 , 7 4 0 , 7 8 1 74 , 2 4 3 , 8 7 5 17 , 4 9 6 , 9 0 5 2,3 9 8 , 3 3 9 (4 6 0 , 6 6 9 ) 76 , 1 8 1 , 5 4 6 15 , 5 5 9 , 2 3 5 75 0 , 1 8 6 16 , 3 0 9 , 4 2 1 5. 1 1 0 0. 7 7 3 33 . 0 9 6. 1 9 2 0. 9 3 6 49 . 6 6 8. 5 5 0 8. 5 5 0 87 , 2 4 1 , 7 9 4 10 , 1 9 6 , 2 2 0 13 . 2 3 % 22 , 5 1 9 , 0 5 6 6, 2 0 9 , 6 3 4 77 , 0 4 5 , 5 7 4 13 . 2 3 % 2,7 6 3 , 1 9 9 96 6 , 4 9 1 96 6 , 4 9 1 15 1 , 5 6 3 1, 1 1 8 , 0 5 4 86 2 , 6 6 2 25 5 , 3 9 2 25 , 1 6 2 (4 , 8 3 3 ) 88 2 , 9 9 0 23 5 , 0 6 3 7, 7 6 7 24 2 , 8 3 1 95 5 , 6 9 1 (1 0 , 8 0 0 ) .1 . 1 2 % 23 6 , 2 5 4 (6 , 5 7 7 ) 96 6 , 4 9 1 -1 . 1 2 % (J ) MU N I C I P A L ST L I G H T (4 1 ) 3, 3 4 , 7 5 8 2, 3 1 4 , 2 6 1 2, 3 1 4 , 2 6 1 36 8 , 8 9 7 2,6 8 3 , 1 5 8 1,9 7 3 , 1 0 1 71 0 , 0 5 7 30 , 4 5 7 (5 , 8 5 0 ) 1, 9 9 7 , 7 0 9 68 5 , 4 5 0 10 , 3 5 6 69 5 , 8 0 6 8.7 8 8 1. 3 2 9 57 . 7 4 20 . 8 0 3 3. 1 4 6 10 4 . 7 9 8.5 5 0 8. 5 5 0 1,6 4 1 , 3 2 2 (6 7 2 , 9 3 9 ) .2 9 . 0 8 % 28 5 , 9 7 7 (4 0 9 , 8 2 9 ) 2,3 1 4 , 2 6 1 .2 9 . 0 8 % (K ) TR F F I C CO N T R O L (4 2 ) 53 4 , 2 3 0 15 5 , 2 0 3 15 5 , 2 0 3 38 , 4 2 0 19 3 , 6 2 3 18 2 , 1 9 3 11 , 4 3 0 18 6 , 1 2 4 21 4 , 7 0 2 59 , 4 9 9 38 . 3 4 % 45 , 6 7 7 36 , 2 3 6 15 5 , 2 0 3 38 . 3 4 % (L ) SC DO E l I N L 17 , 7 6 6 , 9 1 7 5,8 2 8 , 1 7 5 5,8 2 8 , 1 7 5 1, 7 6 7 , 8 7 7 7, 5 9 6 , 0 5 2 7, 0 3 6 , 2 3 8 55 9 , 8 1 4 4, 8 6 5 (9 3 4 ) 16 1 , 7 8 5 (3 1 , 0 7 5 ) 7, 1 6 6 , 9 4 7 7, 4 9 9 42 9 , 1 0 5 1, 9 4 2 9,4 4 1 95 , 1 4 9 52 4 , 2 5 3 1. 7 6 7 0.2 6 7 36 . 8 9 8.5 5 0 7,4 6 1 , 6 6 6 1,6 3 3 , 4 9 1 28 . 0 3 % 1, 5 1 9 , 0 7 1 99 4 , 8 1 8 5, 8 2 8 , 1 7 5 28 . 0 3 % (M ) SC JR S I M P L O T 18 , 3 6 7 , 9 4 9 5, 0 1 8 , 1 5 9 5,0 1 8 , 1 5 9 2,0 9 7 , 7 2 3 7,1 1 5 , 8 8 2 6, 4 3 3 , 0 3 5 68 2 , 8 4 7 16 7 , 2 5 8 (3 2 , 1 2 7 ) 6, 5 6 8 , 1 6 7 54 7 , 7 1 5 85 , 4 4 0 63 3 , 1 5 5 2. 9 5 1 0.4 4 6 27 . 1 1 8. 5 5 0 6,5 5 7 , 2 1 3 1, 5 3 9 , 0 5 4 30 . 6 7 % 1,5 7 0 , 4 6 0 93 7 , 3 0 5 5, 0 1 8 , 1 5 9 30 . 6 7 % Ex h i b i t 3 0 4 (N ) SC MI C R O N 58 , 6 3 8 , 2 8 3 20 , 0 0 3 , 9 5 8 20 , 0 0 3 , 9 5 8 5, 8 4 8 , 0 7 5 25 , 8 5 2 , 0 3 3 23 , 9 9 0 , 1 0 3 1, 8 6 1 , 9 2 9 53 3 , 9 5 9 (1 0 2 , 5 6 2 ) 24 , 4 2 1 , 5 0 0 1, 4 3 0 , 5 3 2 31 5 , 8 6 8 1, 7 4 6 , 4 0 0 3. 4 4 7 0.5 2 1 26 . 4 7 2.9 7 8 0.4 5 0 28 . 4 4 8. 5 5 0 8.5 5 0 25 , 3 6 8 , 6 5 6 5, 3 8 4 , 6 9 8 26 . 8 2 % 5, 0 1 3 , 5 7 3 3, 2 6 7 , 1 7 3 20 , 0 0 3 , 9 5 8 26 . 8 2 %