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Home My WebLink About20100727Stipulation and Settlement.pdfDavid J. Meyer, ESq. Vice President and Chief Counsel of Regulatory and Governental Affairs A vista Corporation 1411 E. Mission Avenue P.O. Box 3727 Spokane, Washington 99220 Phone: (509) 495-4316, Fax: (509) 495-8851 ,. t" , ,:, -:_-) Ri: \. 'l: ~.- ZA.lf' JU\ ')1 IU'" 10: 26U i tiL. L, i ,-" . Donald L. Howell, II Krstine Sasser Deputy Attorneys General Idaho Public Utilties Commission Staff P.O. Box 83720 Boise, ID 83720-0074 Phone: (208) 334-0312, Fax: (208) 334-3762 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION IN THE MATTER OF THE APPLICATION OF AVISTA CORPORATION FOR THE AUTHORITY TO INCREASE ITS RATES AN CHAGES FOR ELECTRIC AN NATUL GAS SERVICE TO ELECTRC AN NATUL GAS CUSTOMERS IN THE STATE OF IDAHO ) ) CASE NOS. A VU-E-10-01 ) A VU-G-1O-01 ) ) ) STIPULATION AND SETTLEMENT ) ) This Stipulation is entered into by and among A vista Corporation, doing business as A vista Utilties ("Avista" or "Company"), the Staff of the Idaho Public Utilties Commission ("Staff), Clearater Paper Corporation ("Clearater"), Idaho Forest Group, LLC ("Idaho Forest"), the Community Action Partnership Association of Idaho ("CAP AI"), the Snake River Alliance ("Snake River"), and the Idaho Conservation League ("Conservation League"). These entities are collectively referred to as the "Paries," and represent all paries in the above-referenced cases that STIPULATION AND SETTLEMENT-AVU-E/G-10-01 Page 1 paricipated in settlement discussions.l The Paries understand this Stipulation is subject to approval by the Idaho Public Utilties Commission ("IPUC" or the "Commission"). I. INTRODUCTION 1. The terms and conditions of this Stipulation are set forth herein. The Paries agree that this Stipulation represents a fair, just and reasonable compromise of all the issues raìsed in the proceeding and that this Stipulation and its acceptance by the Commission represent a reasonable resolution of the multiple issues identified in this Stipulation. The Paries, therefore, recommend that the Commission, in accordance with RP 274, approve the Stipulation and all of its terms and conditions without material change or condition. II. BACKGROUND 2. On March 23, 2010, Avista filed an Application with the Commission for authority to increase revenue from electrc and natural gas service in Idaho by 14% and 3.6%, respectively. If approved, the Company's revenues for electrc base retail rates would have increased by $32.1 milion anually; Company revenues for natural gas servìce would have increased by $2.6 milion anually. The Company requested an effective date of April 23, 2010 for its proposed electrc/natural gas rate increase. By Order No. 31038, dated April 9, 2010, the Commission suspended the proposed schedules of rates and charges for electric and natural gas service for a period of thirty (30) days plus five (5) months, from April 23, 2010, until such time as the Commission enters an Order accepting, rejecting or modifyng the Application in this matter. 3. Petitions to intervene in this proceeding were fied by Clearater, Idaho Forest, CAP AI, the Idaho Conservation League, the Idaho Community Action Network ("ICAN"), Snake River, and North Idaho Energy Logs. By varous orders, the Commission granted these interventions. See, IPUC Order Nos. 31041, 31052, 31054, 31058,31068, 31069 and 31070. i The Idaho Community Action Network and Nort Idaho Energy Logs, Inc., as intervenors, were provided notice of the settlement discussions, but did not paricipate. STIPULATION AN SETTLEMENT - AVU-E/G-10-01 Page 2 4. Public workshops for Avista customers were held on June 28, 2010, in Lewiston, Idaho, and on June 29, 2010, in Coeur d'Alene, Idaho, for the purose of explaining the Company's Application, and in order to provide an opportity for customers to ask questions of Staff. No customers attended the workshop in Lewiston, and approximately five customers attended in Coeur d Alene. Settlement conferences were subsequently noticed and held in the Commission offices on July 6 and 8, 2010, and were attended by signatories to this Stipulation. Furher public customer hearngs have yet to be scheduled. The techncal hearng was previously scheduled to begin on September 22,2010. The Parties' request to modify the procedural schedule wil be the subject of a separate Motion. 5. Based upon the settlement discussions among the Paries, as a compromise of positions in this case, and for other consideration as set forth below, the Paries agree to the following ters: III. TERMS OF THE STIPULATION AND SETTLEMENT 6. Overview of Settlement and Revenue Requirement. The Paries engaged in productive settlement discussions in the conferences on July 6 and 8, 2010. The Parties agree that A vista should be allowed to implement revised tarff schedules designed to recover $21.25 milion in additional anual electric revenue and $1.85 milion in additional anual natural gas revenue, which represent a 9.25% and 2.62% increase in electrc and natural gas annual base tarff revenues, respectively. However, these increases are offset by a rate impact mitigation plan discussed below resulting in a 3.59% increase in electric and a 1.9% increase in gas revenues. New electrc and natural gas rates would become effective October 1,2010. The Paries agree that this settlement is not contingent upon any specific methodology for individual components of the revenue requirement determination, but all Paries support the overall increase to the Company's. revenue requirement, and agree that the overall STIPULATION AND SETTLEMENT - A VU-E/G-10-01 Page 3 increase represents a fair, just and reasonable compromise of the issues in this proceeding and that this Stipulation is in the public interest. 7. Rate Impact Mitigation Plan. The electrc rate impact to customers wil be phased-in, beginning on October 1, 2010, over three years, resulting in a 3.59% increase October 1, 2010, a 3.92% increase on October 1, 2011, and a 1.74% increase on October 1,2012, after giving effect to a two-year amortization of $17 milion of Deferred State Income Tax (DSIT) refund which is being credited to electric ratepayers to mitigate the rate impact. The table below ilustrates this rate mitigation plan in more detaiL. ELECTRIC RATE IMPACT MITIGATION PLAN Revenue Increase of $21.25 millon or 9.25%, partially offset by the amortiation of DSIT over 2 years. Total Increase $21.25 mion $21.25 millon $21.25 mion 9.25% Less - DSIT Credit $13.00 millon $4.00 millon $0.00 mion 0.00% Less - Prior Increase $0.00 mion $8.25 mion 7.51% Net Increase to $8.25 nulloni 3.59%$9.00 nullon 3.92%$4.00 1.74%Customers ! Year 1 (October 1,2010) Year 2 (October 1,2011) Year 3 (October 1,2012) The DSIT reflected on the Company's balance sheet totals approximately $11.1 milion, and when adjusted for the effect of the revenue conversion factor of 0.63676, totals approximately $17.5 milion, representing normalization of state income taxes for a perod of years. As part of this mitigation plan, the Paries agree to credit $17 milion of the DSIT to electrc customers over two years to help offset the rate impact, and $0.5 milion for one year to help offset a portion of the first year natural gas rate increase (thereby reducing the first year impact from 2.6% to 1.9%). The Company wil record regulatory liabilties in Account 254 to account for the $17 milion electric and $0.5 milion gas DSIT refuds, and wil record deferrals for the associated STIPULATION AN SETTLEMENT-AVU-E/G-10-01 Page 4 revenue related expenses and deferred federal income tax. The deferral amounts wil be amortized as the refunds are passed on to customers. The Company wil file, with its compliance filing, tarff schedules 099 (electrc) and 199 (natural gas) which wil be used to pass the DSIT credit back to customers. 8. Recovery of Lancaster Costs. In Case No. A VU-E-09-01, a settlement was reached in which the purchase of the output from the Lancaster combined-cycle generating plant was found to be reasonable with the recovery of the fixed and variable costs through the PCA. Those costs have now been incorporated into the base revenue requirement in this case. 2 9. PCA Authorized Level of Expense. The new level of power supply expense, retail load and Clearater Paper generation, and retail revenue credit rate resulting from the settlement revenue requirement for puroses of the monthly PCA mechanism calculations, are detailed in Attachment A. 10. Prudence of Energy Efficiency Expenditures. The Parties agree that Avista's expenditues for electrc and natural gas energy efficiency programs from Januar 1,2008 through November 30, 2008, and from December 1, 2008 through December 31, 2009 are prudent and recoverable. 11. Cost of Serice. As part of this rate case, the Company prepared an analysis of using a peak credit method of classifying production costs, allocatìng 100% of transmission costs to demand, and allocating transmission costs to reflect any peak and off-peak seasonal cost differences over seven months, rather than assuming an equal weighting over twelve months. The Paries agree to take into account, for purposes of rate spread in this proceeding, the allocation of 100% of transmission costs to demand. The Paries have otherwise agreed to exchange information and convene a public workshop, prior to the Company's next general rate case, with respect to the 2 The Lancaster power plant is a 275 MW gas-fired combined cycle combustion tubine located in Rathdrm, Idao. A vista Utilities will purchase all of the output of the plant through 2026. STIPULATION AN SETTLEMENT - AVU-E/G-10-01 Page 5 possible use of a revised peak credit method for classifyng production costs, as well as consideration of the use of a 12 CP (whether "weighted" or not) versus a 7 CP or other method for allocating transmission costs. The Paries have also agreed to move all electric rate schedules approximately 25% toward unity (except for the Street and Area Lighting Schedules, which wil receive a percentage increase equal to the overall increase in revenue requirement). The following table shows the relative rates of return after giving effect to the foregoing adjustments. 3 ELECTRIC PRESENT & PROPOSED RELATIVE RATES OF RETURN Residential Schedule i General Service Schedule i i Lage General Service Schedule 2 i Ex Large General Servce Schedule 25 Clearater Paper Schedule 25P Pumping Service Schedule 3 i Street & Area Lighting Schedules Overall Present Relative ROR 0.85 1.56 1.8 0.61 0.85 0.79 1.03 1.00 Settlement Relative!i 0.89 1.42 1.4 0.70 0.88 0.85 0.95 1.00 The Paries agreed to move all natual gas rate schedules approximately 60% toward unity (except for Transportation Service Schedule 146, which wil receive a full decrease to unity), as shown below: The following assumptions were used to incorporate the settlement into the cost of servce model for rate spread puroses: (1) Begin with the filed pro form results of operation; (2) input the agreed-upon revised power supply adjustment; (3) reflect power supply changes in production propert adjustment; (4) reflect cost of debt from A VU- E-09-0 1 in restated debt adjustment; (5) determine remaining adjustment necessar to achieve revenue requirement given rate of return from A VU-E-09-01; (6) ru cost of service model on these results using the prior method, except transmission costs are 100% demand (allocated by 12 CP); (7) adjustment amount included as common cost allocated by four-factor allocator; (8) use results to determne rate spread with 25% movement toward unty. STIPULATION AN SETTLEMENT - A VU-E/G-10-01 Page 6 NATUR GAS PRESENT & PROPOSED RELATIVE RATES OF RETURN General Service Sch. 10 1 Large General Service Sch. 111 Interrptible Sales Servce Sch. 13 I Transporttion Servce Sch. 146 Overall Present Relative!i 0.95 1.24 1.0 1.3 1.00 Settlement Relative ROR 0.98 1.0 1.03 1.00 1.00 12. Rate Spread/Rate Design. (a) As indicated above, the Paries agree that the increase in base revenue would be spread to move all electrc rate schedules approximately 25% toward unity (except for the Street and Area Lighting Schedules, which wil receive a percentage increase equal to the overall increase in revenue requirement) and all natural gas rate schedules approximately 60% toward unity (except for Transportation Serice Schedule 146, which wil receive a full decrease to unity). (b) The Paries agree that there wil be an increase in the basic charges, monthly minimum charges, and demand charges in Schedules 11, 21 and 25, as shown in Attachment B. (c) Otherwise, a uniform percentage increase wil be applied to each energy rate within each electric service schedule excluding Schedule 1, residential service where the block differential remains constant. (d) The Paries agree that the curent residential electrc basic charge of $4.60 per month wil be increased to $5.00, and the residential natural gas basic charge of $4.00 per month wil remain the same. (e) Attachment B provides a summar of the current and revised rates and charges (as per the settlement) for electric and natural gas serice. STIPULATION AN SETTLEMENT - A VU-E/G-10-01 Page 7 13. Resulting Percentage Increase by Schedule. The following tables reflect the agreed- upon percentage increase by schedule for electric and natural gas service, along with the first-year net rate impact resulting from the rate impact mitigation plan set forth in Section 7: Electric Increase Percentage by Schedule: General Fit Year Net Rate Schedule Increase with Credit Residentìl SchedlÙe 1 11.0%4.3% General Serce SchedlÙe 11 6.6%2.6% Lage General Servce Schedule 21 8.7%3.4% Ex Lage General Serce SchedlÙe 25 9.8%3.8% Clearater Paper SchedlÙe 25P 7.2%2.8% Pumin Servce SchedlÙe 31 13.5%5.2% Street & Area Ligh Scheduls 9.2%3.6% Overall 9.3°,1 3.6% Natural Gas Increase Percentage by Schedule4: General Fit Year Net Rate Schedule Increase with Credit General Serce SchedlÙe 101 3.4%2.6% Lage General Servce SchedlÙe 111 0.2%-0.3% Intertile Sales Servce SchedlÙe 131 1.0%0.6% Tranporttion Servce SchedlÙe 146 -6.9%-8.6% Overall 2.6%1.9°,1 14. Residential First Tier Energy Blocks. The Parties wil exchange information and convene a public workshop, prior to the Company's next general rate filing, with respect to the appropriate size of the first tier energy block for Residential Electric Service Schedule 1 (curently at 600 Kwhs). 4 As par of this case, the Paries agreed, for puroses of clarty and transparency, to move all natural gas commodity and demand costs from base rates to Schedule 150 (Purchased Gas Cost Adjustment); the retail rate schedules wil now only reflect the non-commodity distrbution rates. The application of the DSIT to natual gas customers would be spread based on each schedule's contribution to base revenues including the general increase in this case. STIPULATION AN SETTLEMENT-AVU-E/G-10-01 Page 8 15. Effective Date for New Rates. The Parties agree, as an integral par of the Settlement, that the effective date for new electrc and natual gas rates should be October 1,2010. 16. Customer Service-Related Issues. (a) Low-Income Weatherization Funding. The Paries agree that the anual level of funding of $465,000 to the Community Action Parnership (CAP) agencies for fuding of weatherization (which includes administrative overhead) should be increased to $700,000. The continuation and level of such funding wil be revisited in the Company's next general rate filing, or other appropriate proceeding. This total amount wil be funded through the Energy Efficiency Tarff Rider (Schedules 91 and 191). (b) Funding for Outreach for Low-Income Conservation. The Parties agree to anual funding of $40,000 to Idaho CAP for purposes of providing low-income outreach and education concernng conservation. This amount wil be funded though the Energy Efficiency Tarff Rider (Schedules 91 and 191), and wil be in addition to the $700,000 of Low-Income Weatherization Funding. The continuation and level of such funding wil be revisited in the Company's next general rate filing or other appropriate proceedings. ( c) Other Serice Commitments. (i) The Company wil review its policies and address in its next general rate case the appropriateness of charging for serices it now provides without charge to customers or other paries, ~, establishing new accounts or managing tenant/andlord accounts. The Company wil also reexamine its existing non- recurrng charges to determine whether those amounts cover a reasonable portion of the Company's current cost to provide those services. (ii) The Company wil use its best efforts to meet or exceed its curent contact center service level standards. STIPULATION AN SETTLEMENT - A VU-E/G-I0-01 Page 9 (iii) In coordination with Staff, the Company wil develop and conduct a study on Avista's deposit policy and practices with respect to residential customers. Among the objectives of the study would be to determine if the current deposit policy correctly identifies customers who pose a credit risk to the Company, whether it encourages customers who pose a credit risk to improve payment habits, and whether it reduces the amount of credit and collection activity as well as bad debt associated with those customer accounts. (iv) The Company wil hold at least five Senìor Energy Conseration workshops in different Idaho communities prior to December 31, 2011. (v) The Company wil begin tracking and reporting to the Commission monthly data regarding customer credit activity. (vi) The Company wil actively monitor the Low Income Weatherzation and Low Income Energy Conservation Education Programs to assure that the stated goals and objectives of these programs are achieved and that costs associated with these programs are prudently incured. (vii) The Company wil work with Commission Staff to address Staffs concerns about Avista's policies and practices with respect to: (a) opening and closing customer accounts, and (b) offering term payment arangements to customers. 17. Other Accounting Treatments. The Paries agree to the accounting treatment for the following items: (a) Coeur d' Alene Tribe Settlement and Spokane River Relicensing Deferrals - The Paries agree to a ten-year amortization of the remaining balances STIPULATION AN SETTLEMENT-AVU-E/G-1O-01 Page 10 beginning October 1, 2010 of the CDA Settlement Deferral, the Spokane River Deferral, and the Spokane River PM&E DeferraL. (b) Colstrip Lawsuit Settlement - The Parties agree to eliminate the amortization of the deferred costs, due to insurance proceeds received subsequent to the original filing of the case. (c) Jackson Prairie (JP) Storage - The parties agree to the revised accounting treatment proposed by the Company for its existing cushion gas using the net book value of the utilty assets at Februar 2010 to record the transfer of the cushion gas from non- recoverable (FERC Account No. 352.3), which is a depreciable asset, to recoverable (FERC Account No. 117.1), which is a non-depreciable asset. The JP assets that wil transfer from Avista Energy on May 1, 2011, wil include plant assets, operations and maintenance expenses, as well as cushion gas that wil be recorded in both recoverable and non- recoverable FERC accounts using a similar allocation method. iv. OTHER GENERAL PROVISIONS 18. The Paries agree that this Stipulation represents a compromise of the positions of the Parties in this case. As provided in RP 272, other than any testimony filed in support of the approval of this Stipulation, and except to the extent necessar for a Party to explain before the Commìssion its own statements and positions with respect to the Stipulation, all statements made and positions taken in negotiations relating to this Stipulation shall be confidential and wil not be admissible in evidence in this or any other proceeding. 19. The Parties submit this Stipulation to the Commission and recommend approval in its entirety pursuant to RP 274. Paries shall support this Stipulation before the Commission, and no Pary shall appeal a Commission Order approving the Stipulation or an issue resolved by the Stipulation. If this Stipulation is challenged by any person not a pary to the Stipulation, the Parties STIPULATION AN SETTLEMENT - A VU-E/G-1O-01 Page 11 to this Stipulation reserve the right to fie testimony, 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 terms embodied in this Stipulation. Notwithstanding this reservation of rights, the Paries to this Stipulation agree that they wil continue to support the Commission's adoption of the terms of this Stipulation. 20. If the Commission rejects any part or all of this Stipulation or imposes any additional material conditions on approval of this Stipulation, each Pary reserves the right, upon written notice to the Commission and the other Paries to this proceeding, within 14 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 Pary 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. In such case, the Paries immediately wil request the prompt reconvening of a prehearing conference for purposes of establishing a procedural schedule for the completion of the case. The Paries agree to cooperate in development of a schedule that concludes the proceeding on the earliest possible date, taking into account the needs of the Paries in paricipating in hearngs and preparing testimony and briefs. 21. The Paries agree that this Stipulation is ìn the public interest and that all of its terms and conditions are fair, just and reasonable. 22. No Pary 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 constred as a waiver of the rights of any Pary unless such rights are expressly waived herein. Execution of this Stipulation shall not be deemed to constitute an acknowledgment by any Pary of the validity or invalidity of any paricular method, theory or principle of regulation or cost recovery. No Pary shall be deemed to have agreed that any method, theory or principle of regulation or cost STIPULATION AN SETTLEMENT-AVU-E/G-1O-01 Page 12 recovery employed in arrving at this Stipulation is appropriate for resolving any issues in any other proceeding in the futue. No findings of fact or conclusions of law other than those stated herein shall be deemed to be implicit in this Stipulation. 23. The obligations of the Paries under this Stipulation are subject to the Commission's approval of this Stipulation in accordance with its ters and conditions and upon such approval being upheld on appeal, ìf any, by a cour of competent jursdiction. 24. This Stipulation may be executed in counterpars and each signed counterpar shall constitute an original document. STIPULATION AN SETTLEMENT - A VU-E/G-10-01 Page 13 .",'2 i.e!DATED this '- dã of July 2010. A vista CorporationB~21¡ avid J. Meyer ¿mey for A vista Corporaon Clearater Paper Corporation By: Peter Richardson Attorney for Clearater Paper Community Action Parnership Association By: Brad M. Purdy Attorney for CAP AI Snake River Allance By: Ken Miller Idaho Public Utilties Commssion Staff By: Donald L. Howell, II Krstine A. Sasser Deputy Attorneys General Idaho Forest Group By: Dean J. Miller Attorney for Idaho Forest Group LLC Idaho Conservation League By: Benjamn J. Otto STIPULATION AND SETTLEMENT - AVU-E/G-lO-Ol Page 14 DATED thisi3~day of July 2010. A vista Corporation By: Davíd 1. Meyer Attorney for A vísta Corporation Clearwater Paper Corporation By: Peter Richardson Attorney for Clearater Paper Community Action Parership Association By: Brad M. Purdy Attorney for CAPAI Snake River Allance By: Ken Miler By: Donald L. well, II Kristine A. Sasser Deputy Attorneys General Idaho Forest Group By: Dean 1. Miler Attorney for Idaho Forest Group LLC Idaho Conservation League By: Benjamin 1. Otto STIPULATION AND SETTLEMENT - A VU-E/G- 10-01 Page 14 DATED ths AvistaCorpration By: David 1. Meyer Attorney for Avista Corporation Co:runty..Aetion..Parership..AsooìåtiOl1 By: Brad M. Purdy Attorney for CAP AI Snake River Alliance By: Ken Miller Idao Public UtWtiesContssionStaff By: DOl1àldLHowell, II KñstneA. Sasse Deput AttoroeysGeneral Idao Fores Group By: Dean J. Miler Attorney for Idaho Forest Grup LLC Idaho ConstvåtìønLeague By: Benam.LOto STIPULATIONANDSETTLEMENT-AVU-E/G..O..Ol Page 14 DATED this ~ day of July 20m. Avista.Corporatiou By: David J. Meyer Attorney for A vista Corporation Clearater Pàper Corpotation By: Peter Richådson Attorney for Clearater Paper Community Action Partership Associatioh By: Brad M.Purdy Attorney forCAPAI Snake River Alliance By: Ken Miller Idaho. Pu.blic Utiliies Coiniission Staf By: Donald L Howen, II Krstine A. Sasser Deputy AttomeysGenerl Id Idaho Conservation League By: Benjamin J. Otto STIPULATION AND SETTLEMENT - A VU-E/G-IO-Ol Page 14 Ju1251006:47p Brad Purdy il- DATED th ~ day of July 2010. Avista Corporation By: David J. Meyer Attorney for A vista Corporation Clearater Paper Corporation By: Peter Richardson Attorney for Clearater Paper Community Action Parnership AssociationBd3~~ Brad M. Purdy Attorney for CAP AI Snake River Allance By: Ken Mí1er 208-384-8511 p.2 Idaho Public Utilties Commission Sta By: Donald L. Howell, II Krstine A. Sasser Deputy Attorneys General Idaho Forest Group By: Dean J. Miler Attorney for Idaho Forest Group LLC Idaho Conservation League By: Benjamin J. Oto STIPULATION AND SETTLEMENT - AVU-E/G-IO-Ol Page 14 07/25/2010 SUN 16:52 (TX/RX NO 5678) ~002 .~ATED ths1J day of July 2()10. Avista Corporation By: David J....Meyer Attorney for Avista Corporation Clearwater Paper Corporation By: Peter Rìchadson Attorney forClearter Paper Community Acton Parership Asociation By: BradNl. Purdy Attorney for CAPAI Snake River Alliance By: Ken MiUer Idaho Public Utilties Commission Staff By: PQUti.dL.HQwel1;II Krstie A. Sasser Deputy Attorneys .G:enerR Idaho Forest Group By: DeanJ. Miler Attorney for Idaho Forest Group LLC Idaho Conservation LeagueBy: A~ Benjamin J. Otto l flu,., fi,.;¡, c: t . STlPULATION AN SETIEMENT ~ Avu-ElG-10~oi.Page 14 DATED this _ day of July 2010. AvistãCorporatiotl By: David J. Meyer Attorney for A vista Corporation Clearwater Paper Corporation By: Peter Richardson Attorney for Clearwater Paper Community Action Partnership Association By: B¡:d.:M.PW'dy Attorney forCAPAI Snake River Allance By: i--rd4~ ler Idaho PublicUtilitiesC:ommission Staff By: Døl1aldL. flowellt II Kristine A. Sasser DeputyAttorneys General Idaho Forest Group By: DeanJ. Miler Attorney for Idaho Forest Group LLC Idaho CoiiservatiOl1League By: Benjamin J. Otto STIPULATION AND SETTLEMENT - A VU-E/G- I 0-0 1 Page 14 RECE 0 ioin JUl27 AM fO: 26 STIPULATION AND SETTLEMENT Case Nos. AVU-E-10-Ol & AVU-G-10-Ol ATTACHMENT A Electric PCA Authorized Expense and Retail Sales Av i s t a C o r p Id a h o P r o f o r m a O c t o b e r 2 0 1 0 . S e p t e m b e r 2 0 1 1 PC A A u t h o r i z e d E x p e n s e a n d R e t a i l S a l e s Ap t 4 1 Ac c o u n t 5 5 5 - P u r c h a s e d P o w e r $9 2 , 3 8 4 , 8 7 9 $ 1 0 . 9 4 1 , 6 1 0 $9 , 2 3 3 , 4 7 5 $9 . 5 3 9 . 0 1 0 $7 , 0 6 3 , 5 4 5 $5 , 3 1 6 . 9 3 4 $5 . 3 6 1 . 2 1 4 $5 . 7 0 1 . 8 9 3 $7 . 1 9 3 . 9 2 8 $5 , 9 5 2 . 0 4 3 $7 , 3 9 0 . 6 7 6 $9 , 4 6 1 . 0 0 4 $9 , 2 2 9 , 5 4 6 Ac c u n t 5 0 1 - T h e r m a l F u e l $3 0 . 8 6 8 , 4 6 4 $3 . 1 0 0 , 3 0 9 $2 . 8 3 5 . 0 1 9 $3 , 0 7 7 . 7 6 2 $1 . 6 7 9 . 3 2 0 $1 , 4 0 4 , 0 6 9 $1 . 3 1 1 , 9 9 7 $2 , 8 0 6 . 6 1 5 $3 . 1 1 2 . 2 3 9 $2 , 9 8 6 , 0 1 0 $2 , 8 8 2 . 5 6 1 $2 , 8 0 2 , 0 2 7 $2 . 8 7 0 , 5 3 8 Ac c u n t 5 4 7 - N a t r u a l G a s Fu e l $1 0 6 , 8 2 4 , 4 6 3 $ 1 0 . 7 2 6 . 2 9 7 $9 . 7 8 6 , 6 4 0 $8 , 2 3 8 . 1 4 4 $3 . 5 9 2 , 0 1 2 $2 . 7 9 3 , 2 6 9 $3 , 3 5 4 , 0 5 5 $ 1 0 , 4 3 1 . 8 3 6 $ 1 2 , 6 8 1 . 6 9 7 $ 1 2 , 1 3 7 , 8 2 8 $9 , 3 7 1 . 7 1 0 $ 1 1 . 1 5 6 . 8 2 8 $ 1 2 , 5 5 4 . 1 4 6 Ac c u n t 4 4 7 - S a l e f o r R e s a l e -$ 5 1 . 2 4 2 . 3 0 7 -$ 2 , 2 2 5 , 2 9 0 -$ 2 . 5 3 0 , 2 4 4 -$ 2 . 6 0 8 . 8 2 8 -$ 3 . 6 4 7 . 3 8 6 -$ 4 , 6 0 6 , 4 0 8 -$ 4 , 7 0 0 , 9 1 9 -$ 5 , 8 1 4 . 1 1 2 -$ 3 . 5 2 8 , 3 3 8 -$ 3 , 3 4 6 . 2 4 4 -$ 4 . 0 1 9 , 9 6 2 -$ 5 . 1 5 7 . 3 3 4 -$ 9 . 0 5 7 , 2 4 1 Po w e r S u p p l y E x p e n s e $1 7 8 , 8 3 5 , 4 9 9 $ 2 2 . 5 4 2 , 9 2 6 $ 1 9 , 3 2 4 , 8 9 0 $ 1 8 , 2 4 6 . 0 8 7 $8 . 6 8 7 , 4 9 0 $4 . 9 0 7 . 8 6 4 $5 , 3 2 6 , 3 4 7 $ 1 3 , 1 2 6 , 2 3 3 $ 1 9 , 4 5 9 , 5 2 6 $ 1 7 . 7 2 9 , 6 3 7 $ 1 5 , 6 2 4 , 9 8 5 $ 1 8 . 2 6 2 , 5 2 5 $ 1 5 , 5 9 6 . 9 8 9 Tr a n s m i s s i o n E x p e n s e $1 7 , 6 4 6 , 4 1 6 $1 , 5 8 3 , 9 1 7 $1 . 4 2 8 , 3 8 5 $1 , 4 8 9 . 8 4 7 $1 , 5 4 5 . 7 2 1 $1 . 3 5 3 , 1 2 6 $1 , 4 3 4 . 1 8 4 $1 , 4 3 3 . 7 5 3 $1 , 4 8 8 . 8 1 1 $1 , 4 4 1 , 8 8 5 $1 , 4 6 4 , 3 1 8 $1 , 4 6 4 , 5 6 5 $1 , 5 1 7 , 9 0 9 Tr a n s m i s s i o n R e v e n u e $1 2 , 3 8 8 , 4 6 0 $9 0 1 . 3 0 4 $8 2 5 . 0 0 4 $1 , 0 0 2 . 2 4 0 $8 9 8 , 4 3 1 $1 , 0 2 9 , 1 0 4 $1 , 3 7 1 , 3 4 7 $1 . 3 7 9 . 8 7 8 $1 , 1 5 0 , 2 0 3 $1 , 0 2 5 , 6 2 9 $1 , 0 4 1 . 3 0 4 $9 3 9 , 3 3 4 $8 2 4 , 6 8 2 30 6 , 3 9 2 27 2 , 0 3 9 26 8 , 0 0 5 23 0 , 6 2 2 lI 1 1 23 2 , 0 9 1 25 0 , 5 3 8 24 7 , 9 2 6 22 8 , 3 4 8 24 6 . 3 8 2 38 , 2 0 6 36 . 6 6 0 39 , 0 7 6 37 , 0 3 2 36 . 7 0 6 Re t a i l S a l e s ( w / o C l e a r w a t e r ) . M W h 3. 0 6 8 . 2 9 4 23 7 , 2 2 1 26 3 . 8 5 4 28 4 , 8 7 5 Cl e a r w a t e r P a p e r G e n e r a t i o n 45 2 , 3 1 7 37 , 7 1 8 33 , 4 6 0 38 , 0 7 6 34 , 4 5 6 40 , 7 1 8 37 , 1 0 8 43 , 1 0 1 Re t a i l R e v e n u e C r e d i t R a t e $4 8 . 0 0 I M W h At c h m e n t A Sti p u l a t i o n a n d S e t t l e m e n t Ca s e N o . A V U - E - 1 0 - 0 1 Av i s t a Pa g e 1 o f 1 STIPULATION AND SETTLEMENT Case Nos. AVU-E-10-Ol & AVU-G-10-Ol ATTACHMENT B Electric and Natural Gas Rate Design AV i S T A U T I U n E S ID A H O E L E C T R I C . C A S E N O . A V U - E - 1 0 - 1 PR O P O S E D I N C R E A S E B Y S E R V I E S C H E D U L E 12 M O N T H S E N D E D D E C E M B E R 3 1 . 2 0 0 9 (O O O o f D o l a r s ) Un e No . Ty p of Se r v e (a aa e T a r i f f B a s e T a r i f f B a s T o t a l B i l l e d G e n . l n c r . T o t a l B i l l e d P e r c e n t Re v e n u e R e v e n u e T a r R e v e n u e a s a % T o l a l Y e a r 1 R e v e n u e I n c n o n Sc h e u l e U n d e r P r e s n t G e n e r a l U n d e r P r o p o s e P è I t a t P r e s e n t o f B l I e d T o t a l G e n O S I T ( S c h . 9 9 ) a t P r o p o s e d B i l l e Nu m b e r R a t e s ( 1 I n c r a s e R a t e s ( 1 ) I n c r e a s e R a t e s ( 2 ) R e v n u e I n c s e O f s e t R a t e s ( 3 ) R e v e n u e ( 4 ) (b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i ) u l ( k ) ( I ) Re s ì d e n t i a l 1 $9 0 , 4 9 5 $9 . 9 8 0 $1 0 0 , 4 7 5 11 . % $9 4 . 1 0 2 10 . 6 % $9 . 9 $ 0 ($ 6 , 1 0 7 ) $9 7 . 9 7 5 4. 1 % 2 Ge n e r a l S e r v i c e 11 . 1 2 $2 9 . 2 4 5 $1 , 9 3 3 $3 1 . 1 7 8 6. % $3 1 . 3 0 1 6. 2 % $1 . 9 3 3 ($ 1 , 1 8 2 ) $3 2 . 0 5 2 2. 4 % 3 la r g G e n e r a l S e r v c e 21 . 2 2 $5 0 . 5 9 7 $4 , 3 9 8 $5 4 , 9 9 5 8. 7 % $5 4 . 7 1 9 8. 0 % $4 . 3 9 8 ($ 2 . 6 9 0 ) $5 6 , 4 2 7 3. 1 % 4 Ex r a l a r g G e n e r a l S e r v i c e 25 $1 2 , 4 5 5 $1 . 2 1 6 $1 3 . 6 7 1 9. 8 % $1 3 . 7 7 4 8. 8 % $1 . 2 1 6 ($ 7 4 3 ) $1 4 , 2 4 7 3. 4 % 5 Cl e a r w e r 25 P $3 9 , 4 5 5 $2 . 8 4 7 $4 2 . 3 0 2 7. 2 . $4 3 . 8 2 7 6. 5 " A . $2 . 8 4 7 ($ 1 . 7 4 3 ) $4 4 , 9 3 1 2.5 % 6 Pu m p i n g S e r v c e 31 . 3 2 $4 . 4 0 $5 9 4 $4 . 9 9 13 . 5 % $4 . 7 5 0 12 . 5 % $5 9 4 ($ 3 6 3 ) $4 . 9 8 1 4.9 % 7 St r e e t & A r a U g h l s 41 - 4 9 ~ 1m ~ 9. 2 % ~ 8. 8 % $2 8 2 íi ~ 3. 4 % 8 To t l $2 2 9 , 6 9 8 $2 1 , 2 5 0 $2 5 0 . 9 4 9. 3 % $2 4 5 . 6 8 5 8. 6 % $2 1 , 2 5 0 ($ 1 3 . 0 0 0 ) $2 5 3 . 9 3 6 3. 4 % (1 ) E x c l u d e s a l l p r e s e n t r a t e a d j u s t m e n t s ( s e e b e ) . (2 ) ~ a l l p r e s e n t r a t e a d j u s t m e n t s ; S c h e d u l e 6 6 - T e m p o r a r y P C A d j . , S c u l e 9 1 - E n e E f f c i e n c y R i d e r A d j . . an d S c d u l 5 9 - R e s i d e n t i a l & F a r m E n e y R a t e A d j . (3 ) ~ a l p r e s e n t a n d p r o p o r a t e a d j u s t m e n t s : S c h e u l e 6 6 T e m p o r a r y P C A A d j . . S c h e d u l e 9 1 - E n e r g y E f f c i e n c y R i d e r A d j . . Sc u l e 5 9 - R e s i d e n t i a l & F a r m E n e r g y R a t e A d j . . a n d S c h e d u l e 9 9 - D e f e r r e d S l a t e I n c e T a x A d j u s t m e n t . (4 ) I n c u d e s o n e y e a r e f f e c o f O S I T ( S c u l e 0 9 ) o f s e t . St i u l a t i o n a n d S e t t m e n t Ca s e N o . A V U - E - 1 0 - 1 A V U - G - 1 0 - 1 Av i Pa g 1 o f 8 At t m e n B AVITA UTILIIES IDAHO ELECTRIC, CASE NO. AVU-E.1o-1 PRESENT & PROPED RATES OF RETURN BY RATE SCHEDULE 12 MONTHS ENDED DECEMBER 31, 200 Prent Rats Base Prop Rat Presnt Pret Tariff Propoed Propd Line Type of Sch.Rate of Relative Proposed Rate of RelatlService~Return BQ Increase Retrn BQ (a)(b)(c)(d)(e)(f)(9) Residential 5.40%0.5 11.0%7.64%0.89 2 General Servce 11,12 9.86%1.56 6.6%12.14%1.42 3 Large General Service 21,22 7.48%1.18 8.7%9.75%1.14 4 Extra Large General Svc.25 3.86%0.61 9.8%5.99%0.70 5 Clearwater 25P 5.35%0.85 7.2%7.52%0.88 6 Pumping Service 31,32 5.01%0.79 13.5%7.27%0.5 7 Street & Area Lights 41-49 6.53%1.03 9.2%8.09%0.95 8 Total 6.32%1.00 9.3%8.55%1.00 Attchment B Stipulatn and Settlement Case No. AVU-E-10-Q1 & AVU-G-1Q-1 Avista Page 2 of 8 AViSTA UTILITIES IDAHO ELECTRIC, CASE NO. AVU-E-10-Q1 PRESENT AND PROPOSED RATE COMPONENTS BY SCHEDULE Present General Proposed Prop Base Tariff ERM&Present Rate BIllng Bas Tarlff Sch.Rate Other AdU1l Billing Rate Increase Bm Bm (a)(b)(c)(d)(e)(t)(g) Residential Seice - Schedule 1 Basic Charge $4.60 $4.60 $0.40 $5.00 $5.00 Energy Charge: First 600 kWhs $0.06950 $0.00313 $0.07263 $0.00825 $0.07573 $0.07775 All over 600 kWhs $0.07867 $0.00313 $0.08180 $0.00824 $0.0848 $0.08691 General Servçes. Scheule 11 Basic Charge $6.50 $6.50 $3.00 $9.50 $9.50 Energy Charge: First 3.650 kWhs $0.08715 $0.00647 $0.09362 $0.0034 $0.09351 $0.09063 All over 3.650 kWhs $0.07433 $0.00647 $0.08080 $0.00298 $0.08019 $0.07731 Demand Charge: 20 kW or less no charge no charge no charge no charge Over20kW $4.00/kW $4.OOW $0.75/kW $4.75/kW $4.75/kW Large General Service. Schedule 21 Enery Charge: First 250.00 kWhs $0.05765 $0.0076 $0.06341 $0.0034 $0.06314 $0.06109 All over 250.000 kWhs $0.04919 $0.00576 $0.05495 $0.00295 $0.05419 $0.05214 Demand Charge: 50 kW or less $275.00 $275.00 $50.00 $325.00 $325.00 Over 50 kW $3.50/kW $3.50/kW $0.75/kW $4.25/kW $4.25/kW Primary Voltage Discont $0.20/kW $0.20/kW $0.20/kW $0.20/kW Extra Large General Service. Schedule 25 Energy Charge: First 500,000 kWhs $0.04709 $0.00510 $0.05219 $0.00356 $0.05324 $0.05065 All over 500,000 kWhs $0.03988 $0.00510 $0.04498 $0.00302 $0.04549 $0.04290 Demand Charge: 3,000 kva or less $10,000 $10.000 $2,000 $12,000 $12,000 Over 3.000 kva $3.25/kva $3.25/kva $0.75/kva $4.oo/kva $4.oo/kva Primary Volt. Discount $0.20/kW $0.20/kW $0.20/kW $0.20/kW Annual Minimum Present:$601.940 $662,400 Clearwater. Schedule 25P Energy Charge: all kWhs Demand Charge: 3,000 kva or less Over 3,000 kva Primary Volt. Discunt Annual Minimum $0.0396 $10,000 $3.25/kva $0.20/kW Present: $0.00490 $0.04450 $10.000 $3.25/kva $0.20/kW $0.00206 $2,000 $0.751va $0.043 $12,000 $4.oo/kva $0.20/kW $602,26 $0.04166 $12,000 $4.00/kva $0.20/kW $555.600 Pumping Service. Schedule 31 Basic Charge Energy Charge: First 165 kW/kWh All additional kWhs $6.50 $0.07800 $0.06649 $0.00586 $0.00586 $6.50 $0.08386 $0.07235 $1.00 $0.01052 $0.00897 $7.50 $0.0881 $0.07585 $7.50 $0.0852 $0.0754 (1) Includes all present rate adjustments: Schedule 66-Temporary peA Adj., Schedule 91-Energy Effciency Rider Adj., and Schedule 59-Residential & Farm Enery Rate Adj. (Sch. 1 only). Attchment B Stipulation and Settlement Case No. AVU-E-10-01 & AVU-G-1Q-01 Avista Page 3 of8 AV I S T A U T I U T I E S ID A H O E L E C T R I C , C A S E N O . A V U - E - 1 0 - G 1 PR O P O S E D D S I T O F F S E T B Y S E R V I C E S C H E D U L E 12 M O N T H S E N D E D D E C E M B E R 3 1 , 2 0 0 9 Ye a r 1 Ye a r 2 Pr o p o s e d Pe r n t a g e Fo r e c s t e d Sc h e d u l e 99 Fo r e c s t e d Sc h e d u l e 9 9 Li n e Ty p e of Sc h e d u l e Re v e n u e of Re v e n u e OS I T kW h ' s Ra t e s OS I T kW h ' s Ra t e s No . Se r v i c e Nu m b e r In c r e a s e In c r e a e S r e a d Oc 1 0 - S e t 1 1 Pe r kW h S r e a d Oc t 1 1 - S e t 1 2 Pe t kW h (a ) (b ) (c ) (d ) (e ) (f ) (g ) (h ) (i ) ü) Re s i d e n t i a l 1 $ 9. 9 8 1 , 8 7 7 46 . 9 7 % $ (6 , 1 0 6 . 5 6 ) 1. 1 8 4 , 7 1 2 , 3 4 7 $ ( 0 . 0 0 5 1 5 ) $ (1 . 8 7 8 . 9 4 2 ) 1, 1 9 9 . 1 8 1 , 4 0 4 $ ( 0 . 0 0 1 5 7 ) 2 Ge n e r a l S e r v i c e 11 . 1 2 $ 1. 9 3 1 , 9 5 8 9. 0 9 % 1 $ (1 . 1 8 1 , 9 0 ) 32 9 , 4 7 5 , 3 8 7 $ ( 0 . 0 0 3 5 9 ) $ (3 6 3 . 6 6 3 ) 34 , 5 6 5 , 3 1 8 $ ( 0 . . 0 0 1 0 6 ) 3 La r g e G e n e r a l S e r i c 21 , 2 2 $ 4. 3 9 7 , 4 8 9 20 . 6 9 % $ (2 . 6 9 , 2 2 9 ) 72 5 . 6 2 2 , 8 3 9 $ ( 0 . 0 0 3 7 1 ) $ (8 2 7 , 7 6 3 ) 75 9 , 1 1 9 . 9 4 1 $ ( 0 . 0 0 1 0 9 ) 4 Ex t r a L a r g e G e n e r l S e r v i c e 25 $ 1. 2 1 4 , 8 1 4 5. 7 2 % $ (7 4 3 . 1 8 0 ) 29 5 , 4 9 9 , 8 0 6 $ ( 0 . 0 0 2 5 1 ) $ (2 2 8 , 6 7 1 ) 30 8 , 4 8 7 , 5 0 8 $ ( 0 . 0 0 7 4 ) 5 C l e a r w t e r 25 P $ 2, 8 4 . 2 7 7 13 . 4 0 % $ (1 , 7 4 2 , 4 7 5 ) 90 4 , 5 6 5 , 6 9 3 $ ( 0 . 0 0 1 9 3 ) $ (5 3 6 , 1 4 6 ) 91 2 . 2 3 9 , 4 7 9 $ ( 0 . 0 0 5 9 ) 6 Pu m p i n g S e r v i c e 31 , 3 2 $ 59 3 , 7 8 2 2. 7 9 % $ (3 6 , 2 5 5 ) 66 , 4 0 9 , 2 1 1 $ ( 0 . 0 0 5 4 7 ) $ (1 1 1 , 7 7 1 ) 69 , 4 8 3 , 8 7 9 $ ( 0 . 0 0 1 6 1 ) 7 S t r e e t & A r e a L i g h t s 41 - 4 9 $ 28 1 , 8 0 3 1. 3 3 % $ (1 7 2 , 3 9 7 1 14 , 3 2 6 , 1 6 5 $ ( 0 . 0 1 2 0 3 ) $ (5 3 , 0 4 5 ) 14 , 5 8 , 3 9 3 $ ( 0 . 0 0 3 6 ) 8 To t a l $ 21 , 2 5 0 , 0 0 0 10 0 % $ (1 3 , 0 0 , 0 0 ) 3, 5 2 0 . 6 1 1 , 4 4 7 $ (4 , 0 0 0 , 0 0 0 ) 3. 6 0 7 , 6 6 2 . 9 2 3 At t a c m e n t B St i p u l a t i n an d S e t t l e m n t ca e N o . A V U - E - 1 Q - 1 & AV U - 1 Q - 1 Av i s t a Pa g e 4 o f 8 AV I S T A U T I L I T I E S ID A H O G A , C A S E N O . A V U - G - l 0 - Ð l PR O P O S E D I N C R E A E B Y S E R V E S C H E D U L E 12 M O N T H E N D E D D E C E M B E R 3 1 . 2 0 0 9 (0 0 0 o f D o l a l ' ) Ba s e T a n Ba s Ba s e T a n Ba e Ta r i Ba To t a l B i l Pe r c e n To t B i Pe r n t Re v U n d Pr o p Ta r i f f Re v e . . U n d Pr o p Re v e n Ta r i f f Re v e n To t a l In c n i a s o n To t a l Re v e . . In c n i a s o n Li n Ty p of Sc u l e Pr e R a l e Ge l Pe r n t Pr e s R a t e s Ge a l U n d P r o p Pe r c n t al P r G e B l l l l R e v e n u e D S I T ( S c h . 1 9 9 ) a t P r Bi I l l & ~ ~ I n c l u e s S c . l 5 0 ~ I n c r l l I 1 E x ç l u d s S c 1 5 0 f 2 1 ~ ~ In c r e ( 2 ) ~ ~ ¡M o r e O S I ! Ql ~ Rm i / 3 \ (a ) (b ) (e ) (d ) (é ) (f ) (g ) (h ) (i) (j (1 \ ) (I I (m ) (n ) (0 ) 1 Ge n e s e 10 1 $5 4 , 4 5 4 $1 . 8 5 0 3. 4 % $2 2 . 2 0 $1 . 8 5 $2 4 . 0 5 5 8.3 % $4 8 . 7 8 3 $ 1 . 8 5 0 3.8 % ($ 4 1 6 ) $5 . 2 1 7 2. 9 % 2 L a e G e S e i c 11 1 $1 5 . 5 5 9 $2 4 0. 2 % $4 , 4 2 6 $2 4 $4 . 4 5 0 0.6 % $1 3 . 5 2 3 $2 4 0.2 % ($ n ) $1 3 , 4 1 0 (0 " ' % ) 3 I n t r u p t i b l e s e 13 1 $2 $3 1. 0 % $1 0 $3 $1 3 4. 2 % $2 4 6 $3 1. 2 % ($ 1 ) $2 4 8 0. 7 " 4 T r a i o S e i c 14 6 $3 9 5 ($ 2 1 ) (6 . 9 % 1 $3 ($ 2 1 ) $3 8 (6 . 9 % ) $3 9 5 ($ 2 7 ) (6 . 9 % ) ($ 6 ) $3 (8 . 3 % ) 5 S p C o r a c t s 14 8 m lQ !l m lQ m !l m lQ !l E m !l 6 To t $1 0 . 1 8 7 $1 , 8 5 2. 6 % $2 7 . 1 0 0 $1 , 8 5 0 $2 9 . 0 3 9 6.8 % $6 . 0 4 0 $ 1 , 8 5 2.9 % ($ 5 ) $6 , 3 9 0 2. 1 % (1 1 T h n e i n s e o f $ 1 . 3 5 0 . 0 0 ( G e n e a l I n c a s l e s D S I T ) a s a p e g e o f B a s e R a t e s ( i n c S c . 1 5 0 ) r e s u i n a n o v e r a . i n s e o f 1 . 9 % . (2 ) N a t u Ga C o m m o i t C o t s m o v e d f r o m b a S a l e S c e s 1 0 S c e 1 5 0 a s p a o f t t i s t i p u . (3 ) I n c o n y e e f e c t o f D S I T ( S c l i 1 9 9 ) o f f s e t At a c n t B St i p i o a n d S e m e n Ce s e N a . A V U " E - l 0 - 1 & A V l - l 0 - 1 Av i s t a Pa g e 5 o f 8 AVISTA UTILITIES IDAHO GAS, CASE NO. AVU-G-10-01 PRESENT & PROPOSED RATES OF RETURN BY RATE SCHEDULE 12 MONTHS ENDeD DeCEMBER 31, 200 Present Raes Base Propo Rates Present Presnt Tanff Proposed Proposed Line Type of Sch.Rate of Relative Proposed Rate of Relative No.Service Number Return f!Increase (1)Return f! (a)(b)(c)(d)(e)(f)(9) General Service 101 7.00%0.95 8.3%8.38%0.98 2 Large General Service 111 9.20%1.24 0.6%9.40%1.10 3 Interrptible Service 131 8.09%1.10 4.2%8.81%1.03 4 Transportation Service 146 9.81%1.33 (6.91)/1))8.55%1.00 5 Total 7.39%1.00 6.8%8.55%1.00 (1) Natural Gas Commodity Costs moved from base Sales Schedules to Schedule 150 ås part of the stipulation. Attachment B Stipulation and Settlement Case No. AVU-E-10-01 & AVU-G-10-Q1 Avista Page 6 of 8 AVISTA UTILITES IDAHO GAS, CAE NO. AVU-G-10-01 PRESENT AND PROPOSED RATE COMPONENTS BY SCHEDULE Current Gas Costs Ne General DSlT (Sch. 199)Pro Proposed Base Moving to Base Present Present Rate Rate Billing BaH13Schedule 150 .B Rate Adj. (2) Billng Rate !.peçre (31 8m 8m (a)(b)(c)(d)(e)(f)(9)(h)(I)(j General Service - Schedule 191 Basic Charge $4.00 $4.00 $0.00 $4.00 $4.00 Usage Charge: All therms $0.87815 ($0.53674)$0.34141 $0.48452 $0.82593 $0.03374 ($9.00729)$U528 $9.37515 LaI Gmral Servlçe - SeluJe 111 Usage Charge: First 200 therms $0.86316 ($0.4820)$0.37796 $0.1720 $0.3916 ($0.0361)$0.39156 $0.3916 200 -1,00 therm $0.7994 ($0.53674)$0.26270 $0.4839 $0.7439 $0.0008 ($9.00361)$0.739 $0.26 1.000 -10.000 therms $0.72485 ($0,53674)$0.18811 $0.4839 $0.66850 $0.00 ($0.00361)$0.6695 $0.18817All over 10.00 therms $0.6841 ($0.53674)$0.14727 $0.4839 $0.62766 ($0.0926)($0.00361)$0.61579 $0.13991 Minimum Charge: per month $75.59 $75.59 $3,44 $79.~$79.3 pertherm $0.00000 $0.0000 $0.4839 $0.4839 ($9.00361)$0.47678 $0.00000 Interrptlbl. Serlçe - Schesule 131 Usae Charge: All Therms $0.61264 ($0.45293)$0.15971 $0.4049 $0.56320 $0.0066 ($0.00280)$9.6710 $0.1667 Tranl!P9rtatlon Service - Schesyie 146 Basic Charge $200.00 $200.00 $0.00 $200.00 $200.00 Usage Charge: All Therms $0.11385 $0.11385 $0.11385 ($0.00826)($0.00159)$0.1040 $0.10559 (1) The New Sase Rate is derved from the Currnt Base Rate. less the Netural Gas Commodity Costs moved to Schedule 150, pnor to th General Rate Increase. (2) Includes Schedule 150 - Purchase Gas Cost Adj., Schedule 155 - Gas Rate Adj., Schedule 191 - Energy Efficency Rider Adj. (3) See Page 8 of Altchmenl A. Attachment B Slipulatlon and Settlement Case No. AVU-E-1Cl01 & AVU-G-1D-l Avist Pae 7 of 8 AV I S T A U T I L I T I E S ID A H O G A S , C A S E N O . A V U - G - 1 0 - 0 1 PR O P O S E D D S I T O F F S E T B Y S E R V I C E S C H E D U L E 12 M O N T H S E N D E D D E C E M B E R 3 1 , 2 0 0 9 To t a l Pe r c e n t a g e o f Fo r e c a s t e d Sc h e d u l e 1 9 9 Li n e Ty p e o f Sc h e d u l e Pr o p o s e d Pr o p o s e d Pr o p o s e d DS I T ( S c h . 1 9 9 ) Th e r m s Ra t e s No . 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