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Home My WebLink About20081009IPC to Micron 1-23.pdfBARTON L. KLINE Lead Counsel .1S1DA~POR(I An IDACORP Company October 8, 2008 VIA HAND DELIVERY Jean D. Jewell, Secretary Idaho Public Utilities Commission 472 West Washington Street P.O. Box 83720 Boise, Idaho 83720-0074 Re: Case No. IPC-E-08-10 General Rate Case Dear Ms. Jewell: Enclosed for filing please find an original and three (3) copies each of Idaho Power Compants Supplemental Response to the Third Production Request of the Commission Staff and Idaho Power Company's Response to Micron Technology, Inc.'s First Set of Discvery Requests. In addition, also enclosed is a CD, four copies, containing the Company's responses - to production requests in which electronic files have been provided and also for ease of production of the information. Upon receipt of this filing, i would appreciate it if you would return a stampedcopy of this letter for my file in the enclosed stamped, self-addressed envelope. Barton L. Kline Lead Counsel for Idaho Power Company BLK:csb Enclosures P.O. Box 70 (83707) 1221 W. Idaho St. Boise, ID 83702 BARTON L. KLINE, ISB #1526 LISA D. NORDSTROM, ISB #5733 DONOVAN E. WALKER, ISB #5921 Idaho Power Company P.O. Box 70 Boise, Idaho 83707 Telephone: (208) 388-2682 Facsimile: (208) 388-6936 bkline(?idahopower.com Inordstrom(?idahopower.com dwalker(?idahopower.com R". .t: (' C I \ ir: 0'~i.vi. v..' iuoa OCT -8 PH a: 54 'Pf~HO PUp,llr'UTILrn£s CO~lt:~IŠSìON Attorneys for Idaho Power Company Street Address for Express Mail: 1221 'West Idaho Street Boise, Idaho 83702 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 POWER COMPANY'S ) RESPONSE TO MICRON ) TECHNOLOGY, INC.'S FIRST SET OF ) DISCOVERY REQUESTS TO IDAHO ) POWER COMPANY COMES NOW, Idaho Power Company ("Idaho Powet' or "the Company"), and in response to Micron Technology, Inc.'s First Set of Discovery Requests to Idaho Power Company dated September 17, 2008, herewith submits the following information: IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 1 REQUEST NO.1: Re: L. Keen pg. 10, L. 1-9. Please identify the degree to which the"... five negative actions by credit rating agency Standard & Poore's (sic) since 2000..." were caused by unregulated trading activities, other unregulated subsidiaries and Idaho Power itself. Please include the full text of the S&P reports describing the negative actions. RESPONSE TO REQUEST NO.1: Idaho Power objects to the first part of this question on the grounds that the request calls for speculation and requests a statement of opinion proscribed by RP 225.01 (a). Without waiving these objections, it is the Company's belief that ratings agencies view IDACORP's recent credit ratings as more closely tied to Idaho Powets performance than to unregulated activities given the extremely small magnitude of unregulated subsidiaries' activities when compared with Idaho Powets activities. While the earlier Standard & Poots ("S&P") reports (2001-2003) did discuss non-regulated energy trading as one of the main reasons for credit actions, the relevant period reports (2003 to present) refer more to Idaho Power specific issues. S&P now focuses on credit metrics, hydroelectric operating conditions, general rate case filings and expected outcomes, and the size of the expected Idaho Power capital program. The context of Mr. L. Keen's testimony on page 10, lines 1-9 refers to the Company's failure to earn its authorized rate of return over each of the last five years as contributing to weakened credit metrics and to the five negative actions by S&P since 2000. With regard to specifically how S&P viewed these items with regard to the five negative actions they have taken since 2000, please see the reports included on the enclosed CD, which speak for themselves. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 2 This response to this Request was prepared by Lawrence F. Spencer, Director of Investor Relations, Idaho Power Company, in consultation wíth Barton L. Kline, Lead Counsel, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 3 REQUEST NO.2: Re: L. Keen, pg 7, L. I 4-21. In addition to the Company's demand-side management efforts, has it considered seasonalizing capacity and energy costs, first to allocate costs to customer classes, and secondly to customer rate design, in order to better control growth in peak demand and energy usage? RESPONSE TO REQUEST NO.2: Yes. In the current case, Case No. IPC-E- 08-10, the Company's preferred class cost-of-service study, the 3CP/12CP study, allocates costs to customer classes based upon seasonalized capacity and energy costs. Furthermore, the proposed rate design for each of the Company's metered service schedules includes energy charges that vary by season. For each of the demand-metered service schedules, the Company has also proposed billng demand charges that vary by season. This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 4 REQUEST NO.3: Please explain whether, and to what extent, the Company has used the seasonal cost variation in its actual capacity and energy costs (as shown in Company Exhibit 50) to spread capacity and energy costs to customer classes. RESPONSE TO REQUEST NO.3: The average monthly marginal cost of energy for the years 2008-2012, as shown on Exhibit No. 50, is included as an input to the 2008 Marginal Cost Analysis, As can be seen on page 49, line 1 of Mr. Tatum's workpapers, the average monthly marginal cost of energy from Exhibit No. 50 is used to compute the monthly "Marginal energy cost at Generation Level" shown on line 5 of page 49. The monthly "Marginal energy cost at Generation Level" values are then used in the derivation of the energy-related allocation factors (E10S and E10NS) as shown on Exhibit No. 68, pages 5 and 6. The resulting energy-related allocation factors are weighted to reflect the seasonal cost variation in the monthly marginal cost of energy. This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 5 REQUEST NO.4: Does the Company agree or disagree that the seasonal cost data shown in its marginal cost study is accurate? RESPONSE TO REQUEST NO.4: The 2008 Marginal Cost Analysis, included in Mr. Tatum's workpapers, pages 46-53, was completed using a methodology based upon the Nation Economic Research Associates Inc. ("NERA") marginal cost model and is consistent with the methodology used by the Company in prior general rate case proceedings. The intent of the 2008 Marginal Cost Analysis is to estimate the monthly marginal cost of energy, generation capacity, and transmission capacity. The resulting values are then used to weight the generation- and transmission-related allocation factors used in the class cost-of-service study. When used for this purpose, the seasonal values derived under the 2008 Marginal Cost Analysis have an acceptable level of accuracy. The seasonalization of the cost data shown in the 2008 Marginal Cost Analysis is based upon information from the Company's 2006 Integrated Resource Plan. A detailed description of how the 2006 IRP information was used to seasonalize the cost data in the 2008 Marginal Cost Analysis is provided on pages 46-48 of Mr. Tatum's workpapers. This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 6 REQUEST NO.5: If failure to use seasonal cost differences to spread cost of service to customer classes can be shown to cause an underpricing of both peak capacity and energy costs, would this contribute to, or exacerbate, Idaho Powets deteriorating system load factor? RESPONSE TO REQUEST NO.5: As discussed in responses to Request Nos. 2, 3, and 4, seasonal cost differences were used to influence the spread of the cost of service to customer classes in the current general rate case proceeding. In addition, the same seasonal cost differences are reflected in the proposed rate design for the Company's metered service schedules. With that said, if it can be shown that an under pricing of both peak capacity and energy costs exists, the resulting customer consumption could contribute to a decrease in the system load factor. This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 7 REQUEST NO.6: Has the Company studied whether or not spreading costs to customer classes based on seasonal cost differences is a cheaper or more effcient means of discouraging peak usage than certain DSM measures? If so, please provide all relevant studies. RESPONSE TO REQUEST NO.6: The Company has not conducted a study to assess whether or not spreading costs to customer classes based on seasonal cost differences is a cheaper or more effcient means of discouraging peak usage than certain DSM measures, This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 8 REQUEST NO.7: Re: J. Gale, pgs. 23-27, has Idaho Power or IDACORP had any independent or outside reviews of its new cost of service studies since the 2007 rate case? RESPONSE TO REQUEST NO.7: No. This response to this Request was prepared by Ric Gale, Vice President of Regulatory Affairs, Idaho Power Company, in consultation with Barton L. Kline, Lead Counsel, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 9 REQUEST NO.8: Re: 7 above. Please provide all written materials and summaries of verbal reports relevant to the response to Request NO.7, above. RESPONSE TO REQUEST NO.8: See Response to Request NO.7. This response to this Request was prepared by Ric Gale, Vice President of Regulatory Affairs, Idaho Power Company, in consultation with Barton L. Kline, Lead Counsel, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 10 REQUEST NO.9: Please provide the most recent marginal cost study prepared by the company. RESPONSE TO REQUEST NO.9: The Company's most recent analysis of the generation and transmission marginal costs is included in Mr. Tatum's workpapers, pages 46-53. The calculations supporting the 2008 Marginal Cost Analysis were provided in electronic format as part of the Company's response to Request No. 10 of the Department of Energy's First Interrogatories and Production Requests. Idaho Power has not recently prepared a full marginal cost study that includes distribution marginal costs along with generation and transmission marginal costs. This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 11 REQUEST NO. 10: Please provide in electronic format the actual Excel workbooks used to prepare the cost of service studies, including all the input data and formulas. RESPONSE TO REQUEST NO. 10: The cost-of-service studies prepared for Case No. IPC-E-08-10 using 2008 test year data were provided in electronic format in the Company's response to Request No. 1 of the Industrial Customers' First Request for Production. This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 12 REQUEST NO. 11: Please provide all cost of service studies prepared by the Company for rate proceedings since 2005. RESPONSE TO REQUEST NO. 11: The cost-of-service studies prepared for Case No. IPC-E-08-10 using 2008 test year data were provided in the Company's response to Request No. 1 of the Industrial Customers' First Request for Production. The cost-of-service studies prepared for Case No. IPC-E-07-08 using 2007 test year data and the study prepared for Case No. IPC-E- 05-28 using 2005 test year data are included on the enclosed CD in Excel format. This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 13 REQUEST NO. 12: Please provide the Company's most recently completed Integrated Resource Plan, as well as any draft plans not yet completed. RESPONSE TO REQUEST NO. 12: The Company's 2006 Integrated Resource Plan and the 2008 Integrated Resource Plan Update are available at the following link: http://ww.idahopower.com/energycenter/irp/2006/2006IRPFinal.htm. This response to this Request was prepared by Karl E. Bokenkamp, General Manager Power Supply Operations and Planning, Idaho Power Company, in consultation with Barton L. Kline, Lead Counsel, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 14 REQUEST NO. 13: Please provide the updated marginal energy costs for the five year period 2007-2011 referred to in the testimony of Mr. Tatum. RESPONSE TO REQUEST NO. 13: The marginal energy costs for the five year period 2008-2012 are included in Mr. Tatum's workpapers, page 49. Marginal energy costs for the five year period 2007-2011 were not computed as part of the 2008 Marginal Cost Analysis. This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY -15 REQUEST NO. 14: Please provide monthly load factors and production for each of the Company's hydro and thermal generating resources, including the three combustion turbines referenced in Mr. Tatum's testimony, for the last five years. RESPONSE TO REQUEST NO. 14: The Company does not calculate load factors for its generation resources. However, included on the enclosed CD is an Excel file containing the monthly output in megawatt-hours and the maximum generating capability for each of the Company's generation resources for the years 2003- 2007 This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 16 REQUEST NO. 15: Please provide all monthly energy and peak hour surplus/deficiency data in numeric format for the years 2007-2011 from the 2006 IRP used to seasonalize marginal generation capacity costs, as discussed in Mr. Tatum's testimony at page 27, lines 13-25, RESPONSE TO REQUEST NO. 15: The monthly energy and peak hour surplus/deficiency data in numeric format for the years 2007-2011 from the 2006 IRP used to seasonalize marginal generation capacity costs are included in Mr. Tatum's workpapers, page 55. Monthly energy and peak hour surplus/deficiency data from 2007 was not used to seasonalize marginal generation capacity costs in the 2008 Marginal Cost Analysis. The 2008 Marginal Cost Analysis used the monthly energy and peak hour surplus/deficiency data for the years 2008-2012. This response to this Request was prepared by Timothy Tatum, Senior Pricing Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 17 REQUEST NO. 16: Please provide monthly system retail sales and coincident peak loads for the last 10 years. RESPONSE TO REQUEST NO. 16: The requested information is included with this production response. This response to this Request was prepared by Timothy Tatum, Senior Pricing . Analyst, Idaho Power Company, in consultation with Barton L. Kline, Senior Attorney, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 18 REQUEST NO. 17: Please provide all LOLP or other capacity risk or load loss studies performed by or for the Company during the last 3 years. RESPONSE TO REQUEST NO. 17: Idaho Power has not performed any LOLP studies during the last 3 years. In both the 2006 IRP and the 2008 IRP, the Company has calculated a capacity planning reserve or capacity planning margin. This analysis is presented in the 2006 Integrated Resource Plan, Appendix D, pages 150 through 153. A similar analysis is presented on page 33 of the 2008 Integrated Resource Plan Update. The Company's 2006 Integrated Resource Plan and the 2008 Integrated Resource Plan Update are available at the following link: http://w.idahopower.com/energycenter/irp/2006/2006IRPFinal.htm . At a regional level, Idaho Power contributed related data to the Western Electricity Coordinating Council's Power Supply Assessments. These annual reports can be viewed on the Council's online library at ww.wecc.biz. This response to this Request was prepared by Karl E. Bokenkamp, General Manager Power Supply Planning & Operations, Idaho Power Company, in consultation with Barton L. Kline, Lead Counsel, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 19 REQUEST NO. 18: Please provide Idaho Power's monthly firm purchased energy amounts during the last three years, identifying the supplier for each purchase. RESPONSE TO REQUEST NO. 18: Please see enclosed CD. This response to this Request was prepared by Dave Bean, Power Supply Controller, Idaho Power Company, in consultation with Barton L. Kline, Lead Counsel, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 20 REQUEST NO. 19: Please provide the forecast of natural gas prices used to prepare the estimated normalized power supply costs for the test period. RESPONSE TO REQUEST NO. 19: The response to this request was previously answered in Idaho Power's response to Request No. 5 of Staffs First Production Request dated August 20,2008. This response to this Request was prepared by Scott Wright, Pricing Analyst, and Gregory W. Said, Revenue Requirement Manager, Idaho Power Company, in consultation with Barton L. Kline, Lead Counsel, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 21 REQUEST NO. 20: Please provide the date the natural gas price forecast referenced immediately above was prepared. RESPONSE TO REQUEST NO. 20: The natural gas' price forecast used for the 2008 Test Year was prepared in March 2008. This response to this Request was prepared by Scott Wright, Pricing Analyst, and Gregory W. Said, Revenue Requirement Manager, Idaho Power Company, in consultation with Barton L. Kline, Lead Counsel, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 22 REQUEST NO. 21: Please provide the NYMEX closing monthly future natural gas prices monthly for the subsequent 12 months after Idaho Power's natural gas price forecasts were prepared. RESPONSE TO REQUEST NO. 21: Idaho Power objects to the extent this Request is vague,ambiguous, imprecise, or utilizes terms subject to multiple interpretations and are not properly defined or explained for purposes of the Request. For instance, Idaho Power cannot ascertain if this Request seeks one monthly report covering a future 12-month period, or 12 monthly reports covering 12-month periods of futures. Notwithstanding and without waiving this objection, Idaho Power has provided, on the enclosed CD, the Henry Hub natural gas futures prices, as they settled daily, from March 3, 2008, through September 17, 2008, for the twelve monthly contracts April 2008 through March 2009. This response to this Request was prepared by Mike Polito, Risk Analyst, Idaho Power Company, in consultation with Barton L. Kline, Lead Counsel, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 23 REQUEST NO. 22: Please provide the NYMEX closing future natural gas prices monthly for the 12 months beginning October 2008. RESPONSE TO REQUEST NO. 22: As it did in Response No. 21, Idaho Power objects to the extent this Request is vague, ambiguous, imprecise, or utilizes terms subject to multiple interpretations and are not properly defined or explained for purposes of this Request. For instance, Idaho Power cannot ascertain if this Request seeks one monthly report covering a future 12-month period, or 12 monthly reports covering 12- month periods of futures. Notwithstanding and without waiving this objection, Idaho Power has provided the Henry Hub natural gas futures prices, on the enclosed CD, as they settled daily from March 3, 2008, through September 17, 2008, for the twelve monthly contracts October 2008 through September 2009. This response to this Request was prepared by Mike Polito, Risk Analyst, Idaho Power Company, in consultation with Barton L. Kline, Lead Counsel, Idaho Power Company. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 24 REQUEST NO. 23: Please update the estimated normalized power supply costs for the test period using the updated future closing NYMEX prices provided in responses to Request Nos. 21 and 22 above. If it is not possible to update the normalized power supply costs for the test period, please estimate the impact of the change in NYMEX prices on normalized power supply costs for the test period. RESPONSE TO REQUEST NO. 23: As it did in Response Nos. 21 and 22, Idaho Power objects to the extent this Request is vague, ambiguous, imprecise, or utilzes terms subject to multiple interpretations and are not properly defined or explained for purposes of this Request. For instance, Idaho Power cannot ascertain if this Request seeks one monthly report covering a future 12-month period, or 12 monthly reports covering 12-month periods of futures. Notwithstanding and without waiving this objection, Idaho Power used the assumptions stated in the previous responses, Request Nos. 21 and 22, to respond to this Request. Idaho Power believes the single index futures gas prices requested in Requests Nos. 21 and 22 are not representative of a normal condition appropriate for ratemaking purposes. Rather, forward market prices reflect current conditions in the near term and revert to normal some time in the future. The gas price forecast Idaho Power develops for its Test Year looks at multiple years arid multiple indices in an attempt to normalize any changes that may occur in the short term market. History shows that natural gas prices are volatile and can change dramatically based on short term changes in the economy, especially when relying on a single price index. While the Company does not believe the requested data is relevant in this case, attached are two spreadsheets that detail the Net Power Supply Expenses of using these NYMEX prices. IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 25 This response to this Request was prepared by Scott Wright, Pricing Analyst, and Gregory W. Said, Revenue Requirement Manager, Idaho Power Company, in consultation with Barton L. Kline, Lead Counsel, Idaho Power Company. DATED at Boise, Idaho, this 8th day of October 2008. BARTOQtl& Attorney for Idaho Power Company LISA D. NORDSTROM Attorney for Idaho Power Company DONOVAN E. WALKER Attorney for Idaho Power Company IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 26 CERTIFICATE OF SERVICE I HEREBY CERTIFY that on this 8th day of October 2008 I served a true and correct copy of IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY upon the following named parties by the method indicated below, and addressed to the following: Commission Staff Weldon B. Stutzman Deputy Attorney General Idaho Public Utilities Commission 472 West Washington P.O. Box 83720 Boise, Idaho 83720-0074 Neil Price Deputy Attomey General Idaho Public Utilties Commission 472 West Washington P.O. Box 83720 Boise, Idaho 83720-0074 Industrial Customers of Idaho Power Peter J. Richardson, Esq. RICHARDSON & O'LEARY PLLC 515 North 27th Street P.O. Box 7218 Boise, Idaho 83702 Dr. Don Reading Ben Johnson Associates 6070 Hil Road Boise, Idaho 83703 Idaho Irrigation Pumpers Association, Inc. Randall C. Budge Eric L. Olsen RACINE, OLSON, NYE, BUDGE & BAILEY, CHARTERED P.O. Box 1391 201 East Center Pocatello, Idaho 83204-1391 -. Hand Delivered U.S. Mail _ Overnight Mail FAX -. Email Weldon.stutzman(?puc.idaho.gov -. Hand Delivered U.S. Mail _ Overnight Mail FAX -. Email Neil.price(?puc.idaho.gov Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email peter(?richardsonandolearv.com Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email dreading(?mindspring.com Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email rcb(?racinelaw.net elo(?racinelaw. net IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 27 Anthony Yankel Yankel & Associates, Inc. 29814 Lake Road Bay Vilage, Ohio 44140 Kroger Co. I Fred Meyer and Smiths Michael L. Kurt Kurt J. Boehm BOEHM, KURTZ & LOWRY 36 East Seventh Street, Suite 1510 Cincinnati, Ohio 45202 The Kroger Co. Attn: Corporate Energy Manager (G09) 1014 Vine Street Cincinnati, Ohio 45202 Kevin Higgins Energy Strategies, LLC Parkside Towers 215 South State Street, Suite 200 Salt Lake City, Utah 84111 Micron Technology Conley Ward Michael C. Creamer GIVENS PURSLEY, LLP 601 West Bannock Street P.O. Box 2720 Boise, Idaho 83701-2720 Dennis E. Peseau, Ph.D. Utilty Resources, Inc. 1500 Libert Street SE, Suite 250 Salem, Oregon 97302 Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email tony(?yankel.net Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email mkurt(?BKLlawfirm.com kboehm(?BKLlawfirm.com Hand Delivered -. U.S. Mail _ Overnight Mail FAX Email Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email khiggins(?energystrat.com Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email cew(?givenspursley.com mcc(?g ivenspursley. com Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email dennytemp(?yahoo.com IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 28 Departent of Energy Lot R. Cooke Arthur Perry Bruder Offce of the General Counsel United States Department of Energy 1000 Independence Avenue SW Washington, DC 20585 Routing Symbol GC-76 Hand Delivered U.S. Mail -. Overnight Mail FAX -. Email Lot.Cooke(?hg.doe.gov Arthur. Bruder(?hg .doe.gov Dwight D. Etheridge Exeter Associates, Inc. 5565 Sterrett Place, Suite 310 Columbia, MD 21044 Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email detheridge(?exeterassociates.com Community Action Partnership Association Of Idaho Brad M. Purdy Attorney at Law 2019 North 17th Street Boise, Idaho 83702 Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email bmpurdy(?hotmail.com Snake River Allance Ken Miler Snake River Alliance P.O. Box 1731 Boise, Idaho 83701 Hand Delivered -. U.S. Mail _ Overnight Mail FAX -. Email kmiler(?snakeriverallance.org ~ IDAHO POWER COMPANY'S RESPONSE TO MICRON TECHNOLOGY, INC.'S FIRST SET OF DISCOVERY REQUESTS TO IDAHO POWER COMPANY - 29 BEFORE THE IDAHO PUBLIC UTiliTIES COMMISSION CASE NO. IPC-E-08-10 IDAHO POWER COMPANY RESPONSE TO REQUEST NO. 16 I Name of Respondent This ~ort Is:Date of Report Year of Report , ,.Idaho i:awer Company (1) X An Original (Mo, Da, Yr)Dec.31,1998 (2) nA Resubmission 04/30/1999 -MONTHLY PEAKS AND OUTPUT 1. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. 2. Report in column (b) the system's energy output for each month such that the total on Line 41 matches the total on Line 20. 3. F-eport in column (c) a monthly breakdown of the Non-Requirements Sales For Resale reported on Line 24. include in the monthly amounts any energy losses associated with the sales so that the total on Line 41 exæeds the amount on Line 24 by the amount of losses incurred (or estimated) in making the Non-Requirements Sales for Resale. 4. Report in column (d) the system's monthly maximum megawatt Load (6o-minute integration) associated with the net energy for the system defined as the difference between columns (b) and (c) 5. Report in columns (e) and (f) the specified information for each monthly peak load reported in column (d). NAME OF SYSTEM: Line Monthly Non-Requirments MONTHLY PEAKSales for Resale & No.Month Total Monthly Energy Associated Losses Megawatts (See Instr. 4)Day of Month Hour (a)(b)(c)(d)(e) 29 January 3,150,981 1,894,117 2,199 9 8am 30 February 3,063,378 2,018,389 2,072 27 8am 31 March 3,380,342 2,188,221 2,081 5 8am 32 April 3,088,840 2,091,980 1,967 30 6pm 33 May 2,617,402 1,484,231 1,981 1 4pm 34 June 2,714,643 1,563,696 2,553 30 5pm 35 July 4,109,511 2,400,198 2,747 14 6pm 36 August 3,695,477 2,223,112 2,593 5 4pm 37 September 3,955,191 2,821,053 2,458 3 7pm 38 October 2,945,520 1,861,639 1,918 30 Bam 39 November 2,828,187 1,599,014 2,015 12 8am 40 Deæmber 2,965,312 1,712,618 2,459 21 8am 41 TOTAL 38,514,784 23,858,268 I I I I I I I I I I I I I I I I I I FERC FORM NO.1 (ED. 12-90)Page 401b II,..... II II II II II, l I - - ~ ~ ~ Name of Respondent This oo0rt Is:Date of Report Year of Report Idaho Power Company (1) X An Original (Mo, Da, Yr)Dec, 31, 1999 (2) ri A Resubmission 04/28/2000 -MONTHLY PEAKS AND OUTPUT 1. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system, 2. Report in column (b) the system's energy output for each month such that the total on Line 41 matches the total on Line 20. 3. Report in column (c) a monthly breakdown of the Non-Requlrements Sales For Resale reported on Line 24. include in the monthly amounts any energy losses associated with the sales so that the total on Line 41 exceeds the amount on Line 24 by the amount of losses incurred (or estimated) in making the Non-Requirements Sales for Resale. 4. Report in column (d) the system's monthly maximum megawatt Load (6o-minute integration) associated with the net energ for the system defined as the difference between columns (b) and (c) 5. Report in columns (e) and (f) the specified infonnation for each monthly peak load report in column Cd). NAME OF SYSTEM:IDAHO POWER COMPANY - SYSTEM LOAD Line Monthly Non-Requinnents MONTHLY PEAKSales for Resale &No.Month Total Monthly Energy Associated Losses Megawatt (See Instr. 4)Day of Month Hour (a)(b)(c).,(d)(e)(f) 29 January 2,485,79f 419,098 2,227 29 8AM 30 February 2,280,967 952,535 2,235 11 BA 31 March 2,088,367 694,281 2,128 5 . BAM 32 April 2,521,645 765,146 1,954 9 BA 33 May 2,521,656 450,611 2,237 25 5PM 34 June 2,492,801 603,363 2,702 15 4PM 35 July 1,291,501 230,756 2,839 13 8PM 36 August 990,853 255,883 2,567 2 5PM 37 September 971,159 454,881 2,051 16 6PM 38 October 1,349,896 583,935 2,151 6 BAM 35 November 1,155,83E 323,672 2,132 3 8AM 40 December 893,69E 139,416 2,228 29 7PM 41 TOTAL 21,04,178 5,873,5n ---- .."""".. .,'" . ,,.1" ..., n",P,"nA 401b Name Ul ~~::¡JVIIU~1I I""~'~r"'-'I _......... .....,...... I . --- _. . --r _.- Idaho Power Company (1) X An Original (Mo, Da, Yr)Dec. 31, 2000 (2) A Resubmission 04/30/2001 -.MONTHLY PEAKS AND OUTPUT 1.If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. 2.Report in column (b) the system's energy output for each month such that the total on Line 41 matches the total on Line 20. 3. Report in column (c) a monthly breakdown of the Non-Requirements Sales For Resale reported on Line 24. include in the monthly amounts any energy losses associated with the sales so that the total on Line 41 exceds the amount on Line 24 by the amount of losses incurred (or estimated) in making the Non-Requirements Sales for Resale. 4. Report in column (d) the system's monthly maximum megawatt Load (6o-minute integration) associated with the net energy for the system defined as the difference between columns (b) and (c) 5. Report in columns (e) and (f) the specified information for each monthly peak load reported in column (d), NAME OF SYSTEM: Line Monthly Non-Requirments MONTHLY PEAKSales for Resale &No.Month Total Monthly Energy Associated Losses Megawatt (See Instr. 4)Day of Month Hour (a)(b)(c)(d)(e)(f) 29 January 1,800,500 460,817 2,266 6 9AM 30 February 1,577,869 428,490 2,132 3 8AM 31 March 1,822,332 643,365 1,978 10 8AM 32 Apnl 1,919,411 791,457 2,000 27 4PM ~3 May 1,686,089 338,590 2,253 23 10PM 34 June 1,818,574 220,719 2,799 29 8PM 35 July 1,970,723 259,142 2,919 12 5PM 36 August 1,849,104 284,891 2,746 2 5PM 37 September 1,687,441 472,823 2,418 14 7PM 38 October 1,361,903 287,617 1,898 4 8AM 39 November 1,394,033 131,368 2,179 17 8AM 40 December 1,500,753 158,150 2,091 8 8PM 41 TOTAL 20,388,732 4,477,429 FERC FORM NO.1 (ED. 12-90)Page _~01b I Name of Respo , " Id~ f,wer Compay Year of Report Dec. 31, 2001 This Re rt s: (1) X An Original (2) A Resubmission MONTHLY PEAKS AND OUTPUT t~s~(lrrr()re powersystems which are not physically integrated, fumish the required information for each non-integrated system. thesyitern'sererw output for each month such that the total on Line 41 matches the total on Line 20. I;r~akdown of the Non~Requirements Sales For Resale reported on Line 24. include in the monthly amounts any. løino that the total on Line 41 excees the amount on Line 24 by the amount of losses incurred (or estimated) in foree~a.le, tlei~t ','.,' ~monthiy maximum megawatt Load (60-minute integration) associated with the net energy for the system defined asthEfd, ',' ,,~ri øoJUrrnS(b)and (c) 5, Report in ooiumns (e) and(f) the specified information for each monthly peak load reported in column (d). I I I Date of Report (Mo, Da, Yr) 04130/2002 I NAME OF SYSTEM: Idaho Power System Load Line No. I I I J J a 41 TOTAL 2,296,96 I I I I I I I I FERC FORM NO.1 (ED. 12-9) Monthly Non-Requirments Sales for Resale & Assoiated Loses (c) Hour (f) 8AM 8AM 8AM 8AM 7PM 6PM 7PM 7PM 5PM 8AM 7PM 8AM MONTHLY PEAK Megawatt (See Instr, 4) Day of Month(d) (e) 2,299 16 2,345 8 2,084 1 1,86 9 2,305 24 2,496 22 2,570 2 2,543 8 2,102 4 1,n4 25 2,059 28 2,030 10 Total Monthly Energy (b) 1,601,850 1,180,64 1,34,827 1,191,295 1,395,732 245,496 5,730 229,445 174,545 170,135 167,014 260,976 224,1n 233,758 165,43 225,981 194,278 1,661,11 1,341,171 1,208,896 1,282,616 1,431,282 16,761,962 Page 401b I. I !'ame of: ~espondent This~rtIS:Date of Report Year of Report Idaho Power Company (1) An Original (Mo, Da, Yr)Dec. 31, 2002 (2) D A Resubmission 04/12003 -MONTHLY PEAKS AND OUTPUT 1.If the respondent has tw or more power systems which are not physically integrated, furnish the required information for each non-integrated system. 2.Report in column (b) the system's energy output for each month such that the total on Line 41 matches the tota on Line 20. 3. Report in column (c) a monthly breakdown of the Non-Requirements Sales For Resale reported on Line 24. include in the monthly amounts any energy losses associated with the saes so that the total on Line 41 excs the amount on Line 24 by the amount of losses incurred (or estimated) in making the Non-Requirements Sales for Resale. 4. Report in column (d) the system's monthly maxium megwatt Load (60minute integration) assoiated with the net energy for the system defined as the difference beteen coumns (b) and (c) 5. Report in columns (e) and (f) the speified information for each monthly peak load reported in coumn (d). NAME OF SYSTEM: Line Monthly Non-Requirments MONTHLY PEAKSales for Resale & No.Month Total Monthly Energy Associated Loses Megawatt (se Ins. 4)Day of Month Hour (a)(b)(c)(d)(e)(f) 29 January 1,614,296 418,746 2,131 29 8AM 30 February 1,165,978 112,210 2,074 5 8AM 31 March 1,310,521 260,652 1,917 4 8AM 3:1 April 1,161,688 207,684 1,719 18 8AM 32 May 1,314,295 136,529 2,365 30 5PM 34 June 1,454,941 63,697 2,822 26 4PM 35 July 1,687,221 86,813 2,963 12 4PM 36 August 1,504,328 110,695 2,529 15 6PM 37 September 1,291,805 165,481 2,310 3 6PM 38 Ocober 1,218,042 164,615 1,93 31 8AM 39 November .1,125,493 62,902 1,912 1 8AM 40 December 1,34,781 172,198 1,942 19 7PM 41 TOTAL 16,192,391 ..1,962,22 I I I I I I I I I I. I I. I.. cca'" cnau Nn 1 ien 1",.on\D,.".. 401h I Name of Respondent 1 his oo0rt Is:Date of Report Year of Reportc "(1) X An Onginal (Mo, Da, Yr)Dec. 31, 2003Idahb Power Company (2) i: A Resubmission 0430/2004 -MONT/iLYPEAKS AND OUTPUT 1.If the respondent has tw or more power systems which are not physically integrated, furnish the required information for each non-integrated system. 2. Report in column (b) the system's energy output for each month such that the total on Line 41 matches the totl on Line 20, 3. Report in column (c) a monthly breakdown of the Non-Requirements Sales For Resale reported on Une 24,include in the monthly amounts any energy loses associated wi the sales so that the total on Line 41 excees the amount on Line 24 by the amount of losses incurred (or estimated) in lTAking the Non-Requirement Sales for Resale. 4. Reprt in column (d) the system's monthly maximum megawatt Load (60-minute integration) assoiated with the net energy for th system defined as the diference between coumns (b) and (c) 5,Report in columns (e) and (f) the speified information for each monthly pek load repoed in coumn (d). NAME OF SYSTEM:Idaho Powr Company - Sysem Lod Line Monhly Non-Requirments MONTHLY PEAKSales for Resale & No.Month Total Montly Energy Associated Loses Megawatt (See Instr, 4)Day of Mon Hour (a)(b)(c)(d)(e)(f) 29 Jliuary 1,253,784 102,502 1,955 7 8AM 3Q Fepruary 1,166,44 141,193 1,974 24 8AM 31 March'1,162,851 141,761 1,n9 4.8AM .,.~~Pril 1,222,50B 241,139 1,715 7 8AM 33 May --1',389;1- ....20,929 2,537 27 5PM 34 June 1,5n,165 97,no 2,759 17 6PM 35 July 1,756,153 ..71,252 2,94 22 5PM $~AI.9ust 1,591,104 124,028 2,674 1 5PM ',':r September 1,367,581 190,047 2,397 3 1PM 38 Ocber 1,220,358 157,928 1,80 2 6PM ~8 N()vember _1,182,61B 73,801 1,949 26 9AM 40 December 1,365,562 178,316 1,961 16 8AM 41 TOTAL 16,255,252 1,726,666. - I I I I I I I I I I I I I 1- I t I I i:i:Ar. i:nAU Nn 1 (i:n 1~.Q\Pane 401b I III:: l\C: Vi \ 10. (1) X An Original (2) A Resubmission MONTHLY PEAS AND OUTPUT (1) Repørt the monthly peak load and energy outut. If the respondent has tw or more power which are not physically integted, furnish the require iofôrtatì~o for each non- integrated system. Qrt on line 2 by month the system's output in Megawatt hours for each month. rIon line 3 by month the non-requirements sales for resale. Incude in the monthly amounts any enery losses associated with the sales. (~)~~rt on line 4 by month the system's monthly maximum megawatt load (60 minute integration) associated with the system. (S)RePQrt on lines 5 and 6 the specfied infrmation for each monthly pek load rePQrted on line 4. Name of Respondent Idal; Powr,COmpany"' ó'" rMõ:Da~ Yr) 0412212005 End of 2004Q4 IDAHO POWER COMPANY - SYSTEM LOAD Monthly Non-Requirments Sales for Resale & Associated Losses (c) MONTHLY PEAK Megawatt (See Instr. 4) (d) Total Monthly Enery (b)2,196 2,072 1,8n 1,758 2,109 2,843 2,825 . 2,792 2,395 1,735 2,063 2,033 72,251 140,373 431,459 . 335,62 302,534 315,058 191,534 221,018 353,612 99,934 106,834 210,950 1,334,01 1,258,7 1,455, 1,370,4 1,493,44 1,750,72 1,780,63 1,683,1 1,525,329 1,173,703 1,202,388 1,433,510 Day of Month (e) 5 13 3 16 4 24 14 22 1 25 30 20 Hour (f) 7PM SA SA 9AM 7PM 5PM 6PM 6PM 5PM SA SA 7PM 17,461,175 2,781,019TOTAL ...... II .FERC FORM NO.1 (ED. 12-90) i Page 401b Name of Respondent This Wort Is:Date of Report Year/Period of Reportldého Powér Company (1) X An Original (Mo, Da, Yr)End of 2005/Q4(2) n A Resubmission 04/18/2006 MONTHLY PEAKS AND OUTPUT (1) Report the monthly peak load and energy output. If the respondent has tw or more power which are not physically integrated, furnish the required information for each non- integrated system. (2) Report on line 2 by month the system's outut in Megawatt hours for each month. (3) Report on line 3 by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. (4) Report on line 4 by month th system's monthly maximum megawatt load (60 minute integration) associated with the system. (5) Report on lines 5 and 6 the specified information for each monthly peak load reported on line 4. NAME OF SYSTEM:IDAHO POWER COMPANY - SYSTEM LOAD Line Monthly Non-Requinnents MONTHLY PEAKNo.Sales for Resale &Month Total Monthly Energy Associated Losses Megawatt (See Instr. 4)Day of Month Hour(a)(b)(c)(d)(e)(f)29 January 1,461,872 226,364 2,063 5 7PM30February1,211,886 154,706 2,072 17 BAM31March1,289,493 234,721 1,812 1 BAM32April1,108,096 107,649 1,796 14 BAM3~May 1,541,433 523,541 1,863 28 6PM3~June 1,655,077 382,243 2,622 21 4PM35July1,874,482 232,642 2,961 22 4PM36August, 1,679,139 140,582 2,815 9 5PM37September1,378,417 188,000 2,394 8 6PMc38October1,229,496 177,730 1,746 5 BAM39November1,247,378 109,44 2,063 28 8AM40December1,541,698 188,624 2,345 15 8AM 41 TOTAL 17,218,467 2,666,246 .";, .-'":'l:'"".l - FERC FORM NO.1 (ED. 12-90)Page 401b I . Name afAespondent ThiS~lOrt Is:Date of Report Year/Period of Report Idaho Power Company (1) X An Original (Mo, Da, Yr)End of 2006/04 (2)A Resubmission 04/1812007 MONTHLY PEAKS AND OUTPUT (1) Report the montly peak load and energy output. If the respondent has tw or more power which are not physically integrated, furnish the required information for each non- integrated system. (2) Report on line 2 by month the system's output in Megawatt hours for each month. (3) Reprt on line 3 by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. (4) Report on line 4 by month the system's monthly maximum megawatt load (60 minute integration) associated with the system. (5) Report on lines 5 and 6 the specifed information for each monthly peàk load reported on line 4. , NAME OF SYSTEM:Idaho Power Company Unè Monthly Non-Requirments MONTHLY PEAKSales for Resale & No.Month Total Monthly Energy Assoiated Losses Megawatt (See Instr. 4)Day of Month Hour (a)(b)(c)(d)(e)(f) 2€January 1,833,131 581,968 2,079 25 8AM 3r Fei:tUàry 1,700,010 581,137 2,144 16 8AM 31 March 1,889,922 750,188 1,946 10 9AM 3~April 1,888,47E 901,44 1,740 6 8AM ~May 2,09,7H 841,211 2,552 17 7PM 3'June 2,031,75~575,510 3,050 27 6PM 3!July 1,930,652 179,104 3,084 24 6PM 3l August 1,778,92E 232,94 2,914 7 6PM 37 September 1,566,O~352,90 2,578 5 6PM 3l October 1,383,41C 284,088 1,997 31 8AM 3~ November 1,283,111 140,164 2,226 29 8AM 4(December 1,636,325 291,187 2,318 18 8AM 41 TOTAL 21,014,495 5,711,85 I I I I I I I I I I I I...I.. FERC FORM NO.1 (ED. 12-90)Page 401b n-T'.'f " .. c~.-TT5T wrr--."'0".""~';."".;"'.'''';¿'''.'' Ths~ortls: (1) llAn Original (2) A Resubmission MONTHLY PEAKS AND OUTPUT it the monthly peak load and energy output. If the respondent has tw or more power which are not physically integrated, fum ish the requiredon for each non- integrated system. rt on line 2 by month the system's outut in Megawatt hours for each month. i:çin line 3 by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated wi the sales. 'rton line 4 by month the system's monthly maximum megawatt load (60 minute integration) associated with the system. l: 9" lines 5 and 6 the specified information for each monthly peak. load reported on line 4. Date of Report (Mo, Da, Yr) 04111/2008 Year/Period of Report End of 2007/04 Idaho Power Company Monthly Non-Requirments MONTHLY PEAKSales for Resale &Totl Monthly Energ Assoiated Losses Megawatts (See Instr. 4)Day of Mont Hour (b)(c)(d)(e)(f)363,38 2,422 16 8AM 211,820 2,268 2 8AM 372,625 2,023 1 7PM 212,871 1,937 30 6PM 1,45,1 92,335 2,484 31 7PM 207,301 3,009 28 6PM 175,571 3,193 13 4PM 205,281 2,90 1 7PM 226,921 2,695 3 7PM 232,723 1,83 31 8AM 145,751 2,130 30 8AM 239,628 2,287 11 8AM TOTAL 18,54,317 2,686,211 1!)..\D.... 401b BEFORE THE IDAHO PUBLIC UTiliTIES COMMISSION CASE NO. IPC-E-08-10 IDAHO POWER COMPANY RESPONSE TO REQUEST NO. 23 IP C O P O W E R S U P P L Y C O S T S F O R 2 0 0 8 N O R M A L I Z E D L O A D S O V E R 8 0 W A T E R Y E A R C O N D I T I O N S MI C R O N D R 2 1 AV E R A G E i! Fe b r u a r y Ma r c h 8e M§ Ju n e Ji 8! Se p t e m b e r Oc t o b e r No v e m b e r De c e m b e r An n u e l Hy d r o e l e c t r i c G e n e r a t i o n ( M W h ) 74 3 , 5 4 8 . 7 88 8 , 8 0 3 . 6 87 0 , 1 1 4 . 3 86 4 , 2 6 8 . 9 86 6 , 4 4 9 . 0 84 2 , 3 9 5 . 2 72 7 , 8 7 3 . 1 68 8 , 0 3 6 . 5 55 5 , 4 7 1 . 4 52 7 , 7 5 9 . 4 47 8 , 3 2 1 . 1 69 5 , 5 2 1 . 7 8,7 4 8 , 5 6 2 . 8 Br i d g e r En e r g y ( M W h ) 45 5 , 1 7 9 . 3 42 5 , 8 1 2 . 9 42 1 , 8 8 9 . 8 33 0 , 3 7 2 . 1 33 0 , 3 4 9 . 2 42 4 , 1 6 3 . 4 45 5 , 1 7 9 . 3 45 5 , 1 7 9 . 3 44 0 , 4 9 6 . 2 45 5 , 1 7 9 . 3 44 0 , 4 9 6 . 2 45 5 , 1 7 9 . 3 5, 0 8 9 , 4 7 6 . 4 Co s t ( $ x 1 0 0 0 ) $ 7,3 3 9 . 2 $ 6,8 6 5 . 7 $ 6,8 0 2 . 4 $ 5, 3 2 6 . 8 $ 5, 3 2 6 . 5 $ 6, 8 3 9 . 2 $ 7, 3 3 9 . 2 $ 7, 3 3 9 . 2 $ 7,1 0 2 . 4 $ 7, 3 3 9 . 2 $ 7, 1 0 2 . 4 $ 7, 3 3 9 . 2 $ 82 , 0 6 1 . 3 Bo a r d m a n En e r g y ( M W h ) 38 , 5 3 5 . 1 35 , 9 1 6 . 3 39 , 0 4 7 . 0 30 , 6 0 4 . 1 6,4 0 6 . 1 27 , 6 3 5 . 0 40 , 2 4 2 . 3 41 , 0 3 8 . 7 39 , 5 4 7 . 0 41 , 0 3 3 . 9 39 , 7 5 5 . 6 41 , 1 1 9 . 9 42 1 , 0 6 3 . 0 Co s t ( $ x 1 0 0 0 ) $ 55 4 . 4 $ 51 7 . 3 $ 56 1 . 0 $ 44 . 8 $ 94 . 0 $ 41 0 . 4 $ 57 5 . 9 $ 58 5 . 8 $ 56 4 . 8 $ 58 5 . 8 $ 56 7 . 4 $ 58 6 . 8 $ 6,0 4 7 . 6 Va l m y En e r g y ( M W h ) 16 3 , 6 9 6 . 2 15 2 , 3 9 9 . 6 16 2 , 4 6 8 . 8 83 , 3 0 2 . 1 15 1 , 6 4 5 . 7 14 7 , 1 9 3 . 5 17 3 , 0 4 . 0 17 4 , 1 7 0 . 4 16 7 , 4 1 9 . 4 17 3 , 6 0 9 . 1 16 8 , 6 6 5 . 6 17 4 , 6 9 4 . 1 1, 8 9 2 , 7 0 9 . 5 Co s t ( $ x 1 0 0 0 ) $ 3,9 5 6 . 0 $ 3, 6 8 0 . 0 $ 3,9 2 3 . 8 $ 2, 0 1 9 . 4 $ 3,6 7 2 . 1 $ 3, 5 7 1 . 9 $ 4,1 6 2 . 1 $ 4, 1 8 7 . 4 $ 4,0 2 6 . 9 $ 4, 1 7 4 . 8 $ 4, 0 5 4 . 9 $ 4, 1 9 9 . 2 $ 45 , 6 2 8 . 6 Da n s k i n En e r g y ( M W h ) 74 4 . 0 18 2 . 9 19 . 9 9.0 0.0 18 8 . 6 16 , 6 2 9 . 0 9, 3 6 6 . 6 1, 2 2 9 . 9 95 0 . 3 4, 2 2 9 . 0 2, 5 5 6 . 4 36 , 1 0 3 . 6 Co s t ( $ x 1 0 0 0 ) $ 96 . 5 $ 24 . 6 $ 2. 5 $ 1. 0 $ 0.0 $ 19 . 9 $ 2, 2 4 2 . 2 $ 1, 1 1 5 . 5 $ 14 6 . 2 $ 10 7 . 2 $ 47 2 . 4 $ 30 3 . 2 $ 4, 5 3 1 . 1 Fi x e d C a p a c i C h a r g e - G a s T r a n s p o r t a t i o n ( $ x 1 0 0 0 ) $ 31 5 . 5 $ 29 6 . 9 $ 31 5 . 5 $ 30 6 . 2 $ 31 5 . 5 $ 30 . 2 $ 31 5 . 5 $ 31 5 . 5 $ 30 6 . 2 $ 31 5 . 5 $ 30 6 . 2 $ 31 5 . 5 $ 3,7 3 0 . 3 To t a l C o s t $ 41 2 . 0 $ 32 1 . 5 $ 31 8 . 0 $ 30 7 . 3 $ 31 5 . 5 $ 32 6 . 1 $ 2, 5 5 7 . 7 $ 1, 4 3 1 . 0 $ 45 2 . 4 $ 42 2 . 7 $ 77 8 . 7 $ 61 8 . 7 $ 8,2 6 1 . 4 Be n n e t t M o u n t a i n En e r g y ( M W h ) 25 . 4 6.7 9. 1 7, 1 6 6 . 7 3, 0 5 6 . 5 10 1 . 1 22 . 5 34 4 . 5 16 1 . 7 10 , 6 9 4 . 2 Co s t ( $ x 1 0 0 0 ) $ 3.4 $ 1. 0 $ $ $ $ 1.2 $ 91 0 . 0 $ 37 6 . 1 $ 13 . 2 $ 2. 8 $ 39 . 9 $ 19 . 8 $ 1, 3 6 9 . 5 Fix e d C a p a c i t y C h a r g e - G a s T r a n s p o r t a t i o n ( $ x 1 0 0 0 ) $ $ $ $ $ $ $ $ $ $ $ $ $ To t a l C o s t $ 3.4 $ 1. 0 $ $ $ $ 1. 2 $ 91 0 . 0 $ 37 6 . 1 $ 13 . 2 $ 2. 8 $ 39 . 9 . $ 19 . 8 $ 1, 3 6 9 . 5 Pu r c h a s e d P o w e r ( E x c l u d i n 9 C S P P ) Ma r k e t E n e r g y ( M W h ) 37 , 1 7 6 . 9 58 3 . 5 57 6 . 0 3,2 1 5 . 9 12 , 5 5 9 . 4 46 , 4 4 7 . 4 14 5 , 9 9 9 . 5 63 , 9 2 7 . 3 46 , 1 3 9 . 4 3,6 3 6 . 4 36 , 6 0 7 . 9 64 , 3 2 2 . 0 46 3 , 5 9 3 . 5 Co n t r a c t E n e r g y ( M W h ) 34 , 6 6 8 . 2 32 , 4 0 1 . 5 35 , 2 7 1 . 0 34 , 3 5 6 . 0 31 , 7 0 9 . 3 68 , 1 4 7 . 5 72 , 5 9 9 . 6 67 , 5 1 1 . 3 30 , 0 3 1 . 7 35 , 4 6 3 . 5 32 , 7 1 6 . 0 42 , 1 7 2 . 1 51 7 , 2 4 9 . 6 To t a l E n e r g y E x c l . C S P P ( M W h ) 72 , 0 4 5 . 1 32 , 9 8 4 . 9 35 , 8 4 7 . 0 37 , 5 7 1 . 8 44 , 2 6 6 . 8 11 4 , 5 9 4 . 9 21 8 , 5 9 9 . 1 13 1 , 4 3 . 6 78 , 1 7 1 . 1 39 , 3 0 1 . 6 69 , 5 2 5 . 9 10 6 , 4 9 4 . 1 98 0 , 8 4 3 . 1 Ma r k e t C o s t ( $ x 1 0 0 0 ) $ 3, 4 9 0 . 3 $ 59 . 0 $ 47 . 3 $ 24 4 . 5 $ 1,0 3 8 . 6 $ 3, 4 5 8 . 4 $ 15 , 4 1 6 . 2 $ 6, 7 5 7 . 6 $ 5, 3 6 6 . 3 $ 42 7 . 2 $ 3, 9 7 6 . 9 $ 6,6 8 1 . 7 $ 46 , 9 6 3 . 9 Co n t r a c t C o s t ( $ x 1 0 0 0 ) $ 1, 7 6 4 . 2 $ 1,6 3 9 . 7 $ 1, 3 1 1 . 4 $ 1, 2 7 7 2 $ 1,1 8 2 . 0 $ 3, 2 5 0 . 2 $ 3, 8 4 1 . 6 $ 3,5 6 0 . 3 $ 1,5 2 3 . 8 $ 1, 7 9 3 . 7 $ 1, 9 8 8 . 0 $ 2,5 5 0 . 5 $ 25 , 6 8 2 . 5 To t a l C o s t E x c l . C S P P ( $ x 1 0 0 0 ) $ 5, 2 5 4 . 5 $ 1,6 9 8 . 7 $ 1, 3 5 8 . 7 $ 1, 5 2 1 . 6 $ 2, 2 2 0 . 5 $ 6,7 0 8 . 5 $ 19 , 2 5 7 . 8 $ 10 , 3 1 7 . 9 $ 6, 8 9 0 . 1 $ 2, 2 2 0 . 9 $ 5, 9 6 . 9 $ 9,2 3 2 . 1 $ 72 , 6 4 6 . 4 Su r p l u s S a l e s En e r g y ( M W h ) 18 9 , 2 3 2 . 7 42 2 , 3 9 2 . 7 42 2 , 7 7 3 . 4 36 3 , 0 0 7 . 5 26 4 , 0 4 . 4 24 1 , 0 8 6 . 0 28 , 9 1 7 . 5 28 , 1 3 4 . 1 10 5 , 1 4 2 . 8 18 2 , 4 8 4 . 1 82 , 9 7 9 . 7 10 1 , 4 8 2 . 3 2, 4 3 1 , 6 7 9 . 0 Re v e n u e I n c l u d i n g T r a n s m i s s i o n C o s t s ( $ x 1 0 0 ) $ 11 , 8 8 2 . 6 $ 29 , 5 1 2 . 7 $ 29 , 6 3 4 . 6 $ 2 0 , 7 5 4 . 8 $ 14 , 2 8 8 . 7 $ 10 , 2 4 1 . 0 $ 2, 1 8 0 . 0 $ 2,3 5 7 . 3 $ 7, 3 0 6 . 7 $ 1 3 , 0 0 . 5 $ 5, 5 2 8 . 5 $ 7,5 9 9 . 1 $ 15 4 , 2 9 2 . 7 Tr a n s m i s s i o n C o s t s ( $ x 1 0 0 0 ) $ 18 9 . 2 $ 42 2 . 4 $ 42 2 . 8 $ 36 3 . 0 $ 26 4 . 0 $ 24 1 . 1 $ 28 . 9 $ 28 . 1 $ 10 5 . 1 $ 18 2 . 5 $ 83 . 0 $ 10 1 . 5 $ 2, 4 3 1 . 7 Re v e n u e E x c l u d i n g T r a n s m i s s i o n C o s t s ( $ x 1 0 0 0 ) $ 11 , 6 9 3 . 4 $ 29 , 0 9 0 . 3 $ 29 , 2 1 1 . 8 $ 2 0 , 3 9 1 . 8 $ 14 , 0 2 4 . 6 $ 10 , 0 0 0 . 0 $ 2, 1 5 1 . 1 $ 2,3 2 9 . 2 $ 7, 2 0 1 . 6 $ 1 2 , 8 2 4 . 0 $ 5, 4 4 5 . 5 $ 7, 4 9 7 . 6 $ 15 1 , 8 6 1 . 0 Ne t P o w e r S u p p l y C o s t s ( $ x 1 0 0 0 ) $ 5, 8 2 6 . 1 $ (1 6 , 0 0 6 . 1 ) $ (1 6 , 2 4 8 . 0 ) $ ( 1 0 , 7 7 2 . 9 ) $ (2 , 3 9 6 . 0 ) $ 7,8 5 7 . 4 $ 32 , 6 5 1 . 6 $ 21 , 9 1 0 . 3 $ 1 1 , 8 4 8 . 3 $ 1, 9 2 2 . 1 $ 13 , 0 6 2 . 8 $ 14 , 4 9 8 . 2 $ 64 , 1 5 3 . 7 IP C O P O W E R S U P P L Y C O S T S F O R 2 0 0 8 N O R M A L I Z E D L O A D S O V E R 8 0 W A T E R Y E A R C O N D I T I O N S MI C R O N D R 2 2 AV E R A G E Ja n u a r y Fe b r u a r y Ma r c h 8w ~ J! i! Au g u s t Se p t e m b e r Oc t o b e r No v e m b e r De c e m b e r An n u a l Hy d r o e l e c t r i c G e n e r a t i o n ( M W h ) 74 3 , 5 4 8 . 7 88 8 , 8 0 3 . 6 87 0 , 1 1 4 . 3 86 4 , 2 6 8 . 9 86 6 , 4 4 9 . 0 84 2 , 3 9 5 . 2 72 7 , 8 7 3 . 1 68 8 , 0 3 6 . 5 55 5 , 4 7 1 . 4 52 7 , 7 5 9 . 4 47 8 , 3 2 1 . 1 69 5 , 5 2 1 . 7 8, 7 4 8 , 5 6 2 . 8 Br i d g e r En e r g y ( M W h ) 45 5 , 1 7 9 . 3 42 5 , 8 1 2 . 9 42 2 , 0 5 0 . 4 33 0 , 3 7 2 . 1 33 0 , 3 1 4 . 7 42 4 , 9 3 7 . 3 45 5 , 1 7 9 . 3 45 5 , 1 7 9 . 3 44 0 , 4 9 6 . 2 45 5 , 1 7 9 . 3 44 0 , 4 9 6 . 2 45 5 , 1 7 9 . 3 5, 0 9 0 , 3 7 6 . 5 Co s t ( $ x 1 0 0 0 ) $ 7, 3 3 9 . 2 $ 6, 8 6 5 . 7 $ 6, 8 0 5 . 0 $ 5,3 2 6 . 8 $ 5, 3 2 5 . 9 $ 6,8 5 1 . 6 $ 7, 3 3 9 . 2 $ 7, 3 3 9 . 2 $ 7, 1 0 2 . 4 $ 7,3 3 9 . 2 $ 7, 1 0 2 . 4 $ 7, 3 3 9 . 2 $ 82 , 0 7 5 . 8 Bo a r d m a n En e r g y ( M W h ) 38 , 5 5 4 . 4 35 , 9 1 3 . 5 39 , 0 5 7 . 7 30 , 8 2 4 . 8 6, 3 9 5 . 3 27 , 6 7 0 . 0 40 , 2 5 9 . 5 41 , 0 3 1 . 9 39 , 5 3 5 . 6 41 , 0 3 9 . 0 39 , 7 5 3 . 2 41 , 1 1 9 . 4 42 1 , 1 5 4 . 3 Co s t ( $ x 1 0 0 0 ) $ 55 4 . 7 $ 51 7 . 3 $ 56 1 . 1 $ 44 4 . 1 $ 93 . 9 $ 41 0 . 8 $ 57 6 . 1 $ 58 5 . 7 $ 56 4 . 7 $ 58 5 . 8 $ 56 7 . 4 $ 58 6 . 8 $ 6,0 4 8 . 5 Va l m y En e r g y ( M W h ) 16 3 , 8 4 2 . 6 15 2 , 4 0 5 . 1 16 2 , 4 9 7 . 8 83 , 3 4 8 . 5 15 1 , 6 5 1 . 9 14 7 , 0 5 5 . 7 17 2 , 8 4 8 . 6 17 3 , 8 8 9 ; 2 16 7 , 1 5 3 . 6 17 3 , 6 3 5 . 9 16 8 , 6 6 0 . 1 17 4 , 6 9 7 . 1 1, 8 9 1 , 6 8 6 . 1 Co s t ( $ x 1 0 0 0 ) $ 3, 9 5 4 . 8 $ 3, 6 8 0 . 1 $ 3, 9 2 4 . 6 $ 2, 0 2 0 . 4 $ 3, 6 6 7 . 8 $ 3, 5 6 8 . 8 $ 4, 1 5 7 . 7 $ 4, 1 8 1 . 1 $ 4, 0 2 0 . 9 $ 4, 1 7 5 . 4 $ 4, 0 5 4 . 8 $ 4, 1 9 9 . 3 $ 45 , 6 0 5 . 6 Da n s k i n En e r g y ( M W h ) 73 9 . 4 19 8 . 5 18 . 0 6. 6 0.1 13 8 . 4 17 , 6 1 2 . 6 8,6 2 1 . 7 1,1 5 9 . 4 1,0 3 8 . 6 4, 3 0 0 . 9 2, 5 6 3 . 8 36 , 3 9 8 . 1 Co s t ( $ x 1 0 0 0 ) $ 95 . 8 $ 26 . 8 $ 2. 3 $ 0.8 $ 0. 0 $ 15 . 4 $ 1, 8 6 7 . 3 $ 89 8 . 0 $ 12 6 . 5 $ 11 7 . 1 $ 47 7 . 9 $ 30 2 . 9 $ 3, 9 3 0 . 7 Fix e d C a p a c i t y C h a r g e - G a s T r a n s p o r t a t i o n ( $ x 1 0 0 0 ) $ 31 5 . 5 $ 29 6 . 9 $ 31 5 . 5 $ 30 6 . 2 $ 31 5 . 5 $ 30 6 . 2 $ 31 5 . 5 $ 31 5 . 5 $ 30 6 . 2 $ 31 5 . 5 $ 30 6 . 2 $ 31 5 . 5 $ 3, 7 3 0 . 3 To t a l C o s t $ 41 1 . 3 $ 32 3 . 7 $ 31 7 . 8 $ 30 7 . 0 $ 31 5 . 5 $ 32 1 . 6 $ 2,1 8 2 . 8 $ 1, 2 1 3 . 5 $ 43 2 . 7 $ 43 2 . 6 $ 78 4 . 1 $ 61 8 . 4 $ 7, 8 8 1 . 0 Be n n e t t M o u n t a i n En e r g y ( M W h ) 27 . 1 6. 2 0. 4 5. 3 6,7 8 8 . 2 2, 7 9 7 . 4 76 . 8 36 . 0 36 3 . 0 15 8 . 5 10 , 2 5 8 . 9 Co s t ( $ x 1 0 0 0 ) $ 3.6 $ 0. 9 $ 0.1 $ $ $ 0. 6 $ 75 7 . 4 $ 30 1 . 6 $ 9. 2 $ 4. 4 $ 42 . 0 $ 19 . 6 $ 1,1 3 9 . 3 Fix e d C a p a c i t y C h a r g e - G a s T r a n s p o r t a t i o n ( $ x 1 0 0 0 ) $ $ $ $ $ $ $ $ $ $ $ $ - $ To t a l C o s t $ 3.6 $ 0.9 $ 0. 1 $ $ $ 0. 6 $ 75 7 . 4 $ 30 1 . 6 $ 9.2 $ 4. 4 $ 42 . 0 $ 19 . 6 $ 1,1 3 9 . 3 Pu r c a s e d P o w e r ( E x c l u d i n g C S P P ) Ma r k e t E n e r g y ( M W h ) 37 , 1 9 4 . 7 57 4 . 7 57 4 . 2 3,2 1 6 . 8 12 , 5 9 9 . 0 46 , 5 0 3 . 0 14 7 , 3 2 3 . 3 64 , 7 3 6 . 9 48 , 2 2 0 . 7 3,8 2 9 . 5 36 , 7 6 5 . 7 64 , 3 5 6 . 1 46 5 , 8 9 4 . 8 Co n t r a c t E n e r g y ( M W h ) 34 , 8 6 8 . 2 32 , 4 0 1 . 5 35 , 2 7 1 . 0 34 , 3 5 6 . 0 31 , 7 0 9 . 3 68 , 1 4 7 . 5 72 , 5 9 9 . 6 67 , 5 1 1 . 3 30 , 0 3 1 . 7 35 , 4 6 3 . 5 32 , 7 1 8 . 0 42 , 1 7 2 . 1 51 7 , 2 4 9 . 6 To t a l E n e r g y E x c l . C S P P ( M W h ) 72 , 0 6 2 . 9 32 , 9 7 6 . 2 35 , 8 4 5 . 2 37 , 5 7 2 . 8 44 , 3 0 8 . 4 11 4 , 6 5 0 . 5 21 9 , 9 2 2 . 9 13 2 , 2 4 8 . 2 78 , 2 5 2 . 4 39 , 2 9 3 . 0 69 , 4 8 3 . 7 10 6 , 5 2 8 . 1 98 3 , 1 4 4 . 3 Ma r k e t C o s t ( $ x 1 0 0 0 ) $ 3, 4 8 7 . 5 $ 58 . 0 $ 47 . 2 $ 24 8 . 2 $ 1, 0 0 0 . 2 $ 3, 1 9 5 . 5 $ 13 , 6 3 3 . 7 $ 5,9 7 2 . 6 $ 4, 9 2 3 . 3 $ 42 6 . 1 $ 3, 9 7 1 . 2 $ 6,6 8 0 . 0 $ 43 , 6 4 3 . 7 Co n t r c t C o s t ( $ x 1 0 0 0 ) $ 1, 7 6 4 . 2 $ 1, 6 3 9 . 7 $ 1,3 1 1 . 4 $ 1, 2 7 7 . 2 $ 1,1 8 2 . 0 $ 3, 2 5 0 . 2 $ 3, 8 4 1 . 6 $ 3,5 6 0 . 3 $ 1,5 2 3 . 8 $ 1, 7 9 3 . 7 $ 1,9 8 8 . 0 $ 2, 5 5 0 . 5 $ 25 , 6 8 2 . 5 To t a l C o s t E x c l . C S P P ( $ x 1 0 0 0 ) $ 5, 2 5 1 . 8 $ 1, 6 9 7 . 7 $ 1,3 5 8 . 6 $ 1, 5 2 5 . 4 $ 2, 1 8 2 . 2 $ 6, 4 4 5 . 7 $ 17 , 4 7 5 . 4 $ 9,5 3 2 . 9 $ 6, 4 4 7 . 1 $ 2, 2 1 9 . 8 $ 5, 9 5 9 . 2 $ 9, 2 3 0 . 5 $ 69 , 3 2 6 . 2 Su r p l u s S a l e s En e r g y ( M W h ) 18 9 , 2 1 3 . 6 42 2 , 4 0 0 . 0 42 2 , 9 7 0 . 8 36 3 , 0 7 3 . 5 26 3 , 8 4 6 . 9 24 1 , 7 8 1 . 8 28 , 6 6 5 . 3 27 , 6 2 9 . 1 10 4 , 8 5 0 . 8 18 2 , 6 0 9 . 4 83 , 0 2 0 . 1 10 1 , 5 2 3 . 3 2, 4 3 1 , 5 8 4 . 4 Re v e n u e I n c l u d i n g T r a n s m i s s i o n C o s t s ( $ x 1 0 0 0 ) $ 11 , 8 8 4 . 3 $ 29 , 5 3 7 . 0 $ 29 , 6 4 7 . 1 $ 2 1 , 0 9 8 . 7 $ 1 3 , 7 2 4 . 5 $ 9, 5 3 9 . 5 $ 1, 8 8 4 . 9 $ 2,0 0 9 . 3 $ 6, 6 5 3 . 5 $ 1 3 , 0 2 9 . 2 $ 5, 5 3 0 . 7 $ 7, 6 0 6 . 4 $ 15 2 , 1 4 5 . 1 Tr a n s m i s s i o n C o s t s ( $ x 1 0 0 0 ) $ 18 9 . 2 $ 42 2 . 4 $ 42 3 . 0 $ 36 . 1 $ 26 3 . 8 $ 24 1 . 8 $ 28 . 7 $ 27 . 6 $ 10 4 . 9 $ 18 2 . 6 $ 83 . 0 $ 10 1 . 5 $ 2, 4 3 1 . 6 Re v e n u e E x c l u d i n g T r a n s m i s s i o n C o s t s ( $ x 1 0 0 0 ) $ 11 , 6 9 5 . 1 $ 29 , 1 1 4 . 6 $ 29 , 2 2 4 . 2 $ 2 0 , 7 3 5 . 6 $ 1 3 , 4 6 0 . 7 $ 9, 2 9 7 . 7 $ 1, 8 5 6 . 2 $ 1, 9 8 1 . 7 $ 6, 5 4 . 7 $ 1 2 , 8 4 . 6 $ 5,4 4 7 . 7 $ 7, 5 0 4 . 9 $ 14 9 , 7 1 3 . 5 Ne t P o w e r S u p p l y C o s t s ( $ x 1 0 0 0 ) $ 5,8 2 0 . 2 $ (1 6 , 0 2 9 . 2 ) $ (1 6 , 2 5 7 . 1 ) $ ( 1 1 , 1 1 1 . 9 ) $ (1 , 8 7 5 . 5 ) $ 8,3 0 1 . 5 $ 30 , 6 3 2 . 4 $ 21 , 1 7 2 . 3 $ 12 , 0 2 8 . 3 $ 1,9 1 0 . 6 $ 13 , 0 6 2 . 3 $ 1 4 , 4 8 8 . 9 $ 62 , 1 4 2 . 9