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HomeMy WebLinkAbout20130910Stipulation.pdfYHFfrII*HI,IOUNTAIN September 9,2013 VIA ELECTRONIC FILING AND OVERNIGHT DELIVERY Jean D. Jewell Commission Secretary Idaho Public Utilities Commission 472W. Washington Boise,ID 83702-5983 Re:CASE NO. PAC.E.13.O2 IN THE MATTER OF THE APPLICATION OF ROCKY MOUNTHN POWER FOR AN ORDER AUTHORIZING A CHANGE IN DEPRXCIATION RATES Dear Ms. Jewell: Please find enclosed for filing an original and seven (7) copies of Rocky Mountain Power's Stipulation in the above referenced case. All formal correspondence regarding this Application should be addressed to: Data Request Response Center PacifiCorp 825 NE Multnomah, Suite 2000 Portland, OR97232 Email : datarequest@nacifi corp.com Informal inquiries may be directed to Ted Weston, Idaho Regulatory Affairs Manager, at (801) 220-2963. :ilir; SI? I il 201 South Main, Suite 2300 Salt Lake City, Utah 841l1 Daniel E. Solander Rocky Mountain Power 201 South Main Street, Suite 2300 Salt Lake City, Utah 841I I Telephone: (801) 220-4014 Fax: (801) 220-3299 Email : daniel. solander@pacifi corp. com Sincerely, Q-lful^^ Daniel E. Solander Senior Counsel Enclosures Service List CERTIFICATE OF SERVICE I hereby certify that on this 9ff of Septemb er,20l3,I caused to be served, via e-mail, a true and correct copy of the foregoing Stipulation on Depreciation Rate Changes in Case No. PAC-E-13-02 to the following: James R. Smith Monsanto Company P.O. Box 816 Soda Springs, Idaho 83276 E-Mail : j im.r. smith@monsanto.com Brubaker & Associates 16690 Swingley Ridge Rd., #140 Chesterfield, MO 63017 E-Mail : bcollins@consultbai.com Ronald L. Williams Williams Bradbury, P.C. l0l5 W. Hays Street Boise, ID 83702 E-mail : ron@williamsbradbury.com Tim Buller PacifiCorp Idaho Industrial Customers Agrium Us Inc.A.,lu-West Industries E-mail : tbul ler@aerium.com Randall C. Budge Racine, Olson, Nye, Budge & Bailey, Chartered 201E. Center P.O. Box 1391 Pocatello, lD 83204-1391 E-Mail: rcb@racinelaw.net Neil Price Attomey Idaho Public Utilities Commission PO Box 83720 Boise, ID 83720-0074 E-mail : nprice@puc. state. id.us Don Schoenbeck RCS,Inc. 900 Washington Street, Suite 780 Vancouver, WA 98660 E-mail: dws@r-c-s-inc.com Carrie Meyer Supervisor, Regulatory Mark C. Moench (8946) Daniel E. Solander (8932) 201 South Main Street, Suite 2300 Salt Lake City, Utah 84111 Telephone No. (801) 220-4014 Facsimile No. (801) 220-3299 mark.moench@pacifi corp. com daniel. solander@pacifi corp. com Attorneysfor RoclE Mountain Power IN THE MATTER OF THE APPLICATION OF ROCKY MOUNTAIN POWER FOR AN ORDER AUTHORIZING A CHANGE IN DEPRECIATION RATES BEF'ORE THE IDAHO PUBLIC UTILITIES COMMISSION ) ) ) ) ) Case No. PAC-E-I3-02 STIPULATION STIPULATION This Stipulation ("Stipulation") is entered into by and among Rocky Mountain Power, a division of PacifiCorp ("Rocky Mountain Power" or the 'oCompany"), Monsanto Company ("Monsanto"), PacifiCorp Idaho Industrial Customers ("PIIC") and Staff for the Idaho Public Utilities Commission ("Staff'), together the "Stipulating Parties." The Stipulating Parties submit this Stipulation on Depreciation Rate Changes ("Stipulation") in resolution of all issues in this Case and request that the Commission approve new depreciation rates for Rocky Mountain Power as stipulated herein to become effective on January t,2014. INTRODUCTION l. The terms and conditions of this Stipulation are set forth herein. The Parties agree that this Stipulation represents afur,just and reasonable compromise of the issues raised in this proceeding and that this Stipulation is in the public interest. The Parties recommend that the Idaho Public Utilities Commission ("Commission") approve the Stipulation and all of its terms and conditions. See IDAPA 31.01.01 .271,272, and 274. PROCEDURAL BACKGROTIND 2. On January 22,2013, Rocky Mountain Power filed its Application for an order authorizing the Company to change depreciation rates effective January 1,2014, together with the direct testimony of Henry E.Lay, John J. Spanos, and K. Ian Andrews. A depreciation study, recommending depreciation rates for all depreciable plant accounts, was an exhibit to the testimony of Mr. Spanos. Based on historical December 31, 2011, plant balances, which were then used to develop projected plant balances and rates as of December 31, 2013, depreciable plant balances and relative allocation factors, Rocky Mountain Power's proposed depreciation rates resulted in an increase in depreciation expense of $4.5 million in Idaho ($8.9 million including the early retirement of the Carbon planD. 3. Monsanto and PIIC were granted intervenor status by the Commission on March 28,2013, and May 8,2013, respectively. 4. On March 22,2013, Staff filed a Decision Memo with the Commission stating that Staff had conducted an initial review of the Application and had been in communication with the Company regarding a collaborative process to include all interested stakeholders potentially affected by the Application. Staff recommended that the Commission issue a Notice of Application and Intervention Deadline , after which the Staff would issue aNotice of Public Workshop to include all interested parties. 5. The Commission issued its Notice of Application on March 28,2013. The Commission issued a press release on May 3,2013, informing the public that Staff would conduct a public workshop on Thursday, May 9, 2013, regarding Rocky Mountain Power's Application. 6. Based upon the discussions at the public workshop, and the settlement discussions between the Stipulating Parties, as a compromise of the positions in this proceeding, and for other consideration as set forth below, the Stipulating Parties agree as follows, subject to the approval by the Commission of the terms and conditions of this Stipulation as described below. TERMS AND CONDITIONS Substantive Terms of the Stipulation 7. The Stipulating Parties, as well as parties from Utah and Wyoming due to the system wide impacts of depreciation, have jointly engaged in good faith, arms-length negotiations in an effort to resolve this matter. The negotiations have resulted in the agreement of the Stipulating Parties on the terms and conditions as set forth herein. 8. The Stipulating Parties agree that the proposed depreciation rates set forth in Attachment 1- Stipulated Rates attached hereto and incorporated herein, represent just and reasonable depreciation rates for Rocky Mountain Power in Idaho commencing January 1,2014. 9. The depreciation rates, originally proposed by the Company in its January 22, 2013, filing, result in an estimated increase in annual depreciation expense across PacifiCorp's six jurisdictions of approximately $160.8 million ($83.9 million excluding the early retirement of the Carbon Plant), based on estimated plant balances as of December 31,2013, before the additional Oregon depreciation expense for shorter coal plant lives. Table I shows the estimated impact of the agreed-upon changes to the depreciation rates on the Company's filed depreciation study. In Attachment 2 - Jurisdictional Allocation, detailed jurisdictional allocations are provided by category. As a result of the settlement discussions, the Stipulating Parties have agreed to the following adjustments to the Company's filed depreciation study and proposed rates, as described in Paragraphs 9-29. These adjustments are sunmarized in Table 2 below and indicate the estimated impact on depreciation expense. (remainder of page intentionally left blank) 4 Table I lncrease in Annual Depreciation Expense Based on Estimated Plant Balances as of December 3'1, 2013 $8.9 $4.5 ($+.21 ($2.21 $4.6 $1.8 $160.8 $83.9 ($72.6) ($45.3) $88.3 $38.6 Table 2 Estimated Imoacts of Depreciation Rate Chanses Adjustment Total Company Wvomins Utah Idaho RMP Original Filing $r 60,8 r3,194 927,269,244 $70,463,058 $8,851,849 A Extend Life on Gadsby to 2032 (379, r 98)(60,244)(159,273')(21,405) B Correct James River life to 2015 and eliminate negative removal cost 626.168 99,481 263,008 35,346 C Reduce net removal cost for CCCT gas production units from $20lkW to $15/kW and change interim retirement curve for Account 343 (2,576,862)(409,382)(1,084,204)(145,878) D Lower Wind Production net removal cost from $9/kW to $7 /kw (32,122)(5,103)(13,492)(1,8 l3) E Reduce Carbon net removal cost from S330/kW to $l l7lkW (27,277,3s8)(4,333,625)(1r,457,239\(1,539,774) F Change Production interim retirement curves: Account 3l I to 120-Rl 5; Account 3 l2 to 68-5o; Account 3 I 4 to 57-S" (6,393,360)( l,015,730)(2,685,386)(360,8e8) G Change Transmission interim retirement curyes: Account 353 to 58- Ss; Account 356 to 60-Rr and merge Account 353.7 with Account 353 (2,546,s05)(404,570)(1,069,602)(143,747) H Distribution changes including merging Distribution Account 362.7 with Account 362 in Utah, Idaho and Wvomins (345,207)(8,654)(102,669)(4,621) I Change net salvage percentages on Minins Accounts 399.41 and399.43 (128,830)(22,821)(54,203)(8,083) J Expedite Amortization Period for Production Excess Reserves to offset Carbon Shortened Life (s,790,21s)(9r9,906)(2,432,049)(326,851) K Expedite Amortization Period for Additional Production Excess Reserves (r,86r,s22)(295,745\(78 r,891)(105,081) L Expedite Amortization Period for Distribution Excess Reserve ( I 9,599,599)(887,03 l )(17,564,617)(1,147,951) M Calculate depreciation rates and remaining lives using June 30, 2013 actual plant and reserve balances for all plant without a designated terminal life (1,906,995)(575,740)(955,628)(n6,192) N Change General Plant lives for Accounts 390,392.09 and 396.03 (2,121,718)(30e,162)(r,246,291)(224,779) o Extend Klamath life to 2022 for Wvomins & Idaho'(2,217,094\(3s2,23s)(r2s,152) SETTLEMENT $88,262,777 $17,768,777 $31,r19,522 $4,614,970 31,2022. I Utah already treats the Klamath-Associated assets as having a depreciable end life of December 10. The Stipulating Parties have agreed to extend the terminal life estimate for the Gadsby Plant from December 31, 2022, to December 31, 2032. This adjustment results in new lower depreciation rates, including the impact of adding estimated interim retirements for the extended period. The stipulated depreciation rates also include recognition of the excess reserve adjustment in the calculation. The stipulated depreciation rates have been computed using an estimated terminal removal rate of $40lkw. (Adjustment A) I 1. The Stipulating Parties have agreed to shorten the terminal life on the James River Plant from December 31,2016, to December 31, 2015, to correct an error in the original Application, and to reduce net salvage estimated in the calculation from -l%o to zero. These changes result in higher depreciation rates. (Adjustment B) 12. The Stipulating Parties agree that, for the Chehalis Plant, Currant Creek Plant, Lake Side Plant, Hermiston Plant and Gadsby Peaker Plant (Units 4-6), the interim retirement curve for Account 343 Prime Movers is changed from a 40-Rr to a 45-Rz.s. There is no change in the proposed terminal removal dates for each of these plants from those presented in the study. The Stipulating Parties agree to lower the terminal removal cost for the CCCT gas units from the Company's proposed level of $20lkW to $15/kW. (Adjustment C) 13. The Stipulating Parties agree that wind generation units will use a 30-year terminal life. The terminal removal cost has been lowered from the Company's proposed level of $9&W to $7/kW. (Adjustment D) 14. The Stipulating Parties agree that the Carbon Plant terminal net salvage estimate is reduced from the proposed $330/kW to $117lkw and the stipulated 6 depreciation rates are calculated based on the April 2015 retirement date. This terminal net salvage estimate of $117lkW is used for calculating rates in this Stipulation and will not be relied on in developing future removal cost estimates for other generation facilities. Until actual results are available, updated current estimates will be provided as needed in future filings, and to the extent the updated estimates differ from the $l l7lkw, this issue can be reexamined in those filings. The amount ultimately deferred for the Carbon Plant will be trued up to actual prudently incurred removal costs in accordance with the procedures set forth in the stipulation in Case No. PAC-E-13-04 (the "GRC Stipulation"). The remaining plant balances for Carbon Plant will be recovered through 2020 consistent with the GRC Stipulation. (Adjustrnent E) 15. The Stipulating Parties accept the Company's proposed method in the study to use Iowa Curves to determine interim retirements for production facilities with terminal lives. The proposed depreciation rates reflect adjustments to the retirement curves on coal generation facilities in Account 3l I Structures and Improvements from 90-Rz to 120-Rr.s, Account 312 Boiler Plant Equipment from 60-Lr to 68-5o and Account 314 Turbogenerator Units from 55-Lr to 57-So. Reliance on the Company's Iowa Curve method for settlement purposes shall not prevent parties from taking a different position on this issue in future depreciation cases. (Adjustment F) 16. The Stipulating Parties agree to extend lives on transmission assets by: (1) extending the curve for Account 353 Station Equipment from the proposed 57-So to a 58-56, (2) extending the curve for Account 356 Overhead Conductors and Devices from 60-R: to 63-R.:; and (3) merging Account 353.7 Supervisory Equipment with Account 353 Station Equipment resulting in a change to the life-curve combination and related net salvage for those assets from the proposed 20-Rz with zero net salvage to 58-So with -5% net salvage. All other lives and retirement curves are accepted as proposed by the Company. Any transmission excess reserve balance will be amortized over the remaining life of the assets rather than on an expedited basis. As part of calculating the stipulated depreciation rates, the depreciation reserve has been redistributed within the transmission function resulting in reduced rates on all accounts within the transmission function and an overall reduction in the composite depreciation rates on those facilities. (Adjustment G) 17. The Stipulating Parties agree to extend lives on distribution assets by merging Account 362.7 Supervisory Equipment with Account 362 Substation Equipment, and using the appropriate state-specific lives for Account 362 in Utah, Idaho and Wyoming. (Adjustment H) 18. The Stipulating Parties agree to amortize net salvage on specific mining accounts as follows: (1) stipulated depreciation rates for Utah mining assets have been established using a terminal life as established in the filed study; (2) net salvage percentages have been adjusted for Account 399.41 Surface Processing Equipment - Preparation Plant from -7%o to -6%o and for Account 399.46 Longwall Equipment from 5%o to 7Yo; and (3) depreciation reserves have been reallocated within the mining accounts. As a result, the stipulated depreciation rates are lower than the Company's proposed rates on most of the mining accounts. (Adjustment I) 19. In order to offset the depreciation expense impacts of the shortened remaining life at the Carbon Plant, which is calculated to be $34.7 million, the Stipulating Parties agree to expedite the amortization of the excess depreciation reserve at the Gadsby Plant and the Hunter Plant. The Stipulating Parties agree that the excess reserve atthe Gadsby Plant and the Hunter Plant, calculated as of December 31, 2011, will be returned on a straight line basis. The excess reserve of $21,073,503 associated with the Gadsby Plant will be amortized based on 9 years and the excess reserve of $29,635,920 associated with the Hunter Plant will be amortized based on 5 years, resulting in an annual amortization of $8.2 million. These amounts will be recorded as a separate item by crediting depreciation expense and debiting the depreciation reserve. The new depreciation rates for the Hunter Plant and Gadsby Plant have been recomputed excluding the above identified amoturts of excess reserye. This recalculation of rates produced an estimated increase in depreciation expense of $2.4 million. Coupled with the $8.2 million excess reserve amount, this results in a net annual decrease in depreciation expense of $5.8 million. The Stipulating Parties agree the excess reserve amortization will occur annually starting January 1,2014, and will continue until the full $34.7 million is returned or ending with the implementation of new rates resulting when new rates from the next depreciation study are implemented. During the next depreciation case, an assessment will be made as to the final disposition of any remaining amount of the $34.7 million which has not been returned at that time. (Adjustment J) 20. The Stipulating Parties agree to amortize depreciation excess reserve for two other steam generationplants with an excess reserve as of December 31,2011, the Blundell Plant with an excess reserve of $7,852,016 and the Colstrip Plant with an excess reserve of $22,930,383, as follows: (l) the annual amount is determined for each plant with any excess reserve by dividing the excess reserve by l0; (2) the annual amortization will occur beginning January 1,2014, until new depreciation rates resulting from the next depreciation study are implemented; and (3) the stipulated depreciation rates are determined by excluding the identified excess reserve in the calculation. This adjustment is intended to offset the large steam plant increase in this Stipulation and does not set precedent for any future depreciation study. (Adjustment K) 21. The Stipulating Parties agree to amortize depreciation excess reserve on distribution plant for Utah, Idaho and Wyoming as follows: the annual amortization has been determined for each state by identifying the excess reserve for each state individually in the Company's filed study as of December 31, 2011, and then dividing the excess reserve for Utah by 6.5 years, the excess reserve for Idaho by 13 years, and the excess reserve for Wyoming by 15 years. The stipulated depreciation rates have been determined by excluding the identified excess reserve amounts from the calculation. The annual amortization will occur beginning January 1,2014, until new depreciation rates from the next depreciation study are implemented. This adjustment is intended to offset the large steam plant increase in this Stipulation and does not set precedent for any future depreciation study. (Adjustment L) 22. The Stipulating Parties agree to stipulated depreciation rates calculated using June 30, 2013, actual account balances within specific functions without terminal lives, including transmission, Utah, Idaho and Wyoming distribution and Utah, Idaho and Wyoming general plant. (Adjustment M) 23. The Stipulating Parties agree to adjust general plant lives to be consistent with the Oregon Settlement. Utah, Idaho and Wyoming depreciation rates have been adjusted using the life-curve combinations agreed to in Oregon. For Idaho, Account 390 Structures and Improvements, the life has been changed from 55& to 58-Rr, Account 10 392.09 Transportation Equipment-Trailers from 33-Lzto 34-Lz and Account 396.03 Light Power Operated Equipment from 8-Rz to 9-Lg. Each state's estimated salvage remains as provided in the Company's originally filed depreciation study. (Adjustment N) 24. For the depreciation rates for Wyoming and ldaho, the Stipulating Parties agree to adjust Klamath-Accelerated depreciation to an end date of December 31, 2022, consistent with the approved life in Utah. The life may be reassessed in the next depreciation cases in Wyoming and ldaho. If Klamath-Accelerated facilities are retired prior to December 31,2022, return of and on any remaining balance will continue after retirement of the facilities as though it remained in service through December 31,2022, and the Stipulating Parties agree not to challenge this recovery based on "used and useful" arguments. (Adjustment O) 25. The Stipulating Parties agree to the Company's proposal to move the balance of communication equipment to mass asset accounting with a consistent 24-year life and a depreciation rate of 4.3%. The depreciation reserves will continue to be maintained on a state basis which ensures no inadvertent jurisdictional transfer of depreciation reserve benefits created from different depreciation rates historically being used by each state. 26. The Stipulating Parties agree that the Company will provide a section in the next depreciation study, for informational purposes only, listing the specific mining assets, reserve balances, and respective lives owned by its Wyoming mining subsidiary. 27. A new depreciation study will be filed with the Idaho Public Utilities Commission no later than five years from the date of the written order resolving the issues in this Docket, or as otherwise ordered by the Commission. The Stipulating Parties 1l agree the Company will maintain the right to file a new depreciation study sooner than five years. 28. The Stipulating Parties agree the Company will implement a reporting system to keep the Stipulating Parties and the Utah, Idaho and Wyoming Commissions informed regarding any matters likely to have implications regarding potential stranded costs of generating assets. The Company will propose a reporting method by no later than December 31,2013. 29. The Stipulating Parties agree the Company will provide updated cost estimates regarding Carbon Plant's terminal net salvage, including any new third-party studies as part of the Company's next general rate cases in Idaho, Utah and Wyoming. 30. The Stipulating Parties agree to adhere to the depreciation study treatment established according to paragraphs 10-14 of the Stipulation in Case PAC-E-13-04 (the "GRC Stipulation") if approved by the Idaho Public Utilities Commission. The parties are requesting that the stipulated depreciation rates from this study be effective on January l, 2014 for purposes of financial reporting. Per the GRC Stipulation, the Company will establish a regulatory asset that will track for further recovery or refund, the aggregate net difference between the depreciation expense that would have been booked beginning in2014 under the depreciation rates in effect as of the date of the GRC Stipulation and the depreciation expense actually booked beginning in 2014 under the depreciation rates approved by the Commission in this Case until the new depreciation rates are reflected in customer rates. Recovery of the deferral shall be allocated to customers on a proportionate basis, based on the cost of service relationships established t2 in the next Idaho general rate case with rates proposed to be effective on or after January 1,2016, as modified by future cost of service studies in future rate cases. 31. General Terms and Conditions To the extent this Stipulation calls out specific rates, or includes any discussion of rates for states other than Idaho, those discussions are for illustrative purposes only, and the Stipulating Parties do not intend to bind other state commissions or create precedent in other states. 32. The Parties agree that this Stipulation represents a compromise of the positions of the Parties on all issues in this proceeding. Other than the above referenced positions and any testimony or comments filed in support of the approval of this Stipulation, ffid except to the extent necessary for a Party to explain before the Commission its own statements and positions with respect to the Stipulation, all negotiations relating to this Stipulation shall not be admissible as evidence in this or any other proceeding regarding this subject matter. 33. The Parties submit this Stipulation to the Commission and recommend approval in its entirety pursuant to IDAPA 31.01.01.274. The Parties request that the Commission notice the filing of the Stipulation and establish a procedural schedule, including public and technical hearings as necessary, for the review and consideration of the Stipulation by the Commission. The Parties shall support this Stipulation before the Commission, and no Party shall appeal any portion of this Stipulation or Order approving the same. If this Stipulation is challenged by any person not a party to the Stipulation, the Parties to this Stipulation reserve the right to cross-examine witnesses and put on such case as they deem appropriate to respond fully to the issues presented, including the right to raise issues that are incorporated in the settlement embodied in this Stipulation. 13 Notwithstanding this reservation of rights, the Parties to this Stipulation agree that they will continue to support the Commission's adoption of the terms of this Stipulation. 34. In the event the Commission rejects or modifies any part or all of this Stipulation, or imposes any additional material conditions on approval of this Stipulation, each Party reserves the right, upon written notice to the Commission and the other Parties to this proceeding, within 15 days of the date of such action by the Commission, to withdraw from this Stipulation. In such case, no Party shall be bound or prejudiced by the terms of this Stipulation, and each Party shall be entitled to seek reconsideration of the Commission's order, file testimony as it chooses, cross-examine witnesses, and do all other things necessary to put on such case as it deems appropriate. 35. The Parties agree that this Stipulation is in the public interest and that all of its terms and conditions are fair, just and reasonable. 36. No Party shall be bound, benefited or prejudiced by any position asserted in the negotiation of this Stipulation, except to the extent expressly stated herein, nor shall this Stipulation be construed as a waiver of the rights of any Party unless such rights are expressly waived herein. Execution of this Stipulation shall not be deemed to constitute an acknowledgment by any Party of the validity or invalidity of any particular method, theory or principle of regulation or cost recovery. No Party shall be deemed to have agreed that any method, theory or principle of regulation or cost recovery employed in arriving at this Stipulation is appropriate for resolving any issues in any other proceeding in the future. No findings of fact or conclusions of law other than those stated herein shall be deemed to be implicit in this Stipulation. t4 37. The obligations of the Parties under this Stipulation are subject to the Commission's approval of this Stipulation in accordance with its terms and conditions and, ifjudicial review is sought, upon such approval being upheld on appeal by a court of competent j urisdiction. BASED ON THE FOREGOING, the Stipulating Parties request that the Commission issue an Order approving this Stipulation and adopting the terms and conditions of this Stipulation. RESPECTFULLY SUBMITTED: August _,2013. Mark C. Moench Daniel E. Solander Attorneys for Roclcy Mountain Power Randall C. Budge Attorneyfor Monsanto ra tJ/(',,t/ t U -- ffi Attorney for P aciJiCorp ldaho Industrial Customers Attorney for ldaho Publ ic Utilities Conunission Staff D. Neil Ptice l5 37. The obligations of the Parties undsr this Stipulation are subjeot to the Commission's apprroval of this Stipnluion in accordance with its tcrms and conditions ard, ifjudicial revie$, is soWnq upon such approval bciug upheld on appeal by a court of competeirt j urisdiction BASED ON THE FORECTOING, the Stipulating Parties request that the Commission issrre an Odor this Stipuldion and adopdng the tms aod conditions of this Stipulation RESPECTIII.TLLY SUBMTTED: Angrrst 12013. Daniel E. Solmdcr Attornqs for Rocky Motptah Pover Randall C. Budge Anorncyfor l,{onsanto Ronald Williams Attomey for PrcifiCorp ldalo It dusffial Castonurs D. Nail Price Attorney for ldalo Public Utilities Coruntsston &0ff l5 37. The obligations of the Parties under this Stipulation ane subject to the Cornmission's approval of this Stipulation in accordance with its tenns and conditions an4 ifjudicial review is sougfut, upon such approval being upheld on appeal by a corut of competent juridiction. BASED ON TIIE FOREGOING, the Stipulating Parties r€quest that the Cmunission issue an Ordcr approving this Stipulation and adopting the terrns and conditions of this Stiplatioa. RESPECTFTTLLY SUBMITTED: August _,2013. Mark C, Moe,nch Daniel E. Solander Attorneysfor Ro&y Mwntain Power Ronald lfr/illiams Ataruey for P acitiC orp ldaho Infits trial Customers D. 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