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Home My WebLink About20020304Production Responses.pdfJohn M. Eriksson STOEL RIvES LLP 201 South Main Street, Suite 1100 Salt Lake City, Utah 84111 Telephone: (801) 328-3131 Facsimile (801) 578-6999 Mary S. Hobson STOEL RIVES LLP 101 South Capitol Blvd., Suite 1800 Boise, Idaho 83702-5958 Telephone: (208) 389-9000 Facsimile (208) 389-9040 Attorneys for PacifiCorp F:ECEIVED iLED fxlL.v r:1 t~1\ "'" _ 1. ~ : ?'" " r "- ,,, '7 t , , J J , ; ', . ' '"JLJ dfILITi,:S CUr~;'i!SSIO;1 BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION In the Matter of the Application of ACIFICORP dba Utah Power & Light Company for Approval of Changes to Its Electric Service Schedules CASE NO. PAC-02- PACIFICORP'S RESPONSES TO THE FIRST PRODUCTION REQUEST OF IDAHO IRRIGATION PUMPERS ASSN PacifiCorp hereby responds to the First Production Request of the Idaho Irrigation Pumpers Association to PacifiCorp as follows. PacifiCorp' s response to Request TIP A 1.6 will be forthcoming later. PacifiCorp s Res~onses to TIPA' First Production Request PacifiCorplP AC- February 5, 2002 lIP A Data Request No. 1. lIP A Data Request No. 1. Please provide a listing of all Finn sales-for-resale contracts with duration of one month or more that were either initiated or revised after December 31 , 1997. For each such contract or contract revision, please provide: A copy of the contract (in case of new) and/or the original contract as well as contract revision (in the case of a revision); A copy of the previous contract that may have been in place (even if it was not the same type of contract or contract revision); A listing of the nonnalized MWH, MW, and dollars for each month from January 1999 through December 2001; A listing of the actual MWH, MW, and dollars fot each month from January 1999 through December 2001. Response to lIP A Data Request No. 1.1: Copies of the wholesale sales contracts that have tenns longer than one year are provided as Attachment IIPA No. 1.1a. Because of the volume of these documents, a copy is being provided to the requesting party only. If other parties desire a copy, please contact the company. Contracts for transactions that have tenns of one year or less are voluminous. They can be reviewed at Company s headquarters in Portland, Oregon, given adequate advance notice. Please refer to above. Please refer to Response to lIP A Data Request No. 14. In addition the expected level of MWh, MW and dollars are specified in the contracts. Please refer to Response to lIP A Data Request No. 14. Witness: Mark T. Widmer --" IDAHO CASE NO. PAC-O2- , PACIFICORP lIP A DATA REQUEST ATTACHMENT IIPA l.l(a) \..- IDAHO CASE NO. PAC-O2- ACIFICORP \...I lIP A DATA REQUEST ATTACHMENT lIP A l.l(b) IDAHO CASE NO. PAC-O2- P A CIFI CO lIP A DATA REQUEST ATTACHMENT lIP A l.l(b) \.,.) , . \.J Energy Purchasl Original (0 Central Files - 550 LCT Copied for Confirm Files Apri.1 20, 2000 Paul. Wood Paci.fi.corp 9951 SE Ankeny Portl.and, OR 97216 Fax No.(503) 256-6168 CONFIRMM:ION IB':r'JER Daa1 No. 326704. Enron Power Marketing. Inc. O. Sox 4428 Houston. Texas 7721~428 (FAX) (713) 646-2491 .-... . ; \ l-' This l.etter shal.l. confirm the agreement reached on April. 20, 2000 between Paci.ficorp and Enron Power Marketing, Inc. ("EPMI") regarding the sal.e of Firm Power under the terms and conditions that fo1l.ow: ./ Sel.1er:Enron Power Marketing, Inc. , Buyer:Paci.f i corp Monday, January 1, 2001 through Friday, December 31, 2004.Hour Endi.ng (HE) 0700 through HE 2200 (16 Hours each day), Mondaythrough Saturday onl.y, exc1uding NERC Hol.i.days: Paci.fic Prevai.1ing Time. ... Term: Type ofCommodity:Firm Power PrJ.ce:US Dol.l.ars $41. 50/HHh. Quantity:25 Mws of Fir:m Power per hour. Del.iveryPoint(s) :COB N/s Schedul.ing: EBHcr Real. ':rime Operati.ons: 1-800-684-1336 Firm Power is power that is or wil.l. be schedul.ed in accordance with Appl.ica.bl.e Reserve Requirements for which the onl.y excuses for fai.l.ure to del.iver or receJ.ve are if an interruptJ.on is (i) due to an Uncontrol.l.abl.e Force as provided J.n Section 10 of the Agreement: or (ii) where app1icabl.e, to meet Sel.l.er' publ.ic uti1ity or statutory obl.igations to its customers. If Se11er exerci.ses its right to interrupt to meet its pub1ic util.i.ty or statutory obl.i.gations, Sel.l.er shal.l. be responsibl.e for payment of damages for fai.l.ure to del.iver Fir:m Power as provJ.ded in SectJ.on 21.3 of the Agreement. Applicab1e Reserve Requirements" means WSCC operating reserves. D~ No. 326704. Thi.s confi.rmati.on l.etter i.s bei.ng provi.d8d pursuant to and :in accordance wi.th' Western SystlilJlls Power Pool. Agreement ("WSPP Agreement"), as amended peri.odi.cal.l.y wi.th FERC approval., to whi.ch Paci.fi.corp and EPMI are parti.es. ':rerms used but not de:fi.ned herei.n shal.1 have the meani.ngs ascribed to them i.n the WSPP Agreement. Pl.ease confi.rm that the terms stated here:in accuratel.y refl.ect the agreement reached on Apri.l. 20, 2000 between you and EPMI by ret:l1rni.ng an executed copy of thi.s l.etter by facsi.mi.l.e to EP~ at (713) 646-2491. Your response shoul.d refl.ect the appropri.ate party i.n your organi.zation who has the authori.ty to enter i.nto thi.s transacti.on. If you have any questions pl.ease cal.l. (713) 853-1886. Paci.fi.corp Enron Power Marketi.ng, Inc. By:J:eL By:iSJ.L Name:Name: Tim Bel.den Title:Title:Vi.ce Presi.dent . ' 8i' '-',", MAY-B4-2000 13:23 ~I=l. TA 4B3 267 6906 P . 1112/23 May 4, 2000 Terry Hudgens, Senior Vice PresidentPacifiC~ 825 N.E. Multnomah, Suite 2000 portland, cnegon 97232 Dear Mr. Hudgens: PacifiCc?rp and TransAJta Energy Marketing (U.) Inc. ('"TEMUS") are both Parties to the version of the Western Systems Power Pool Agreement, effective Fc:bn1ary 1.2000 WSPP Agreement"). This Confmnation Agreement ("Confmnation Agreement") setS out the understanding reached betWeen the representatives of our organizations concerning the sale of energy by TEMUS to PacifiCorp under the termS and conditions of the WSPP Agreement and Service Schedule C (fum energy - C2 as amended or replaced), both as supplemented and modified below. TEMUS and PacifiCorp are individually referred (0 herein as a .'Party" and collectively Is the .'panics Section 1 - Definitions 24-Hour Index" means the Dow JonesTM Telerate Mid-Columbia 24-Hour F1l1I1 electricity index for the applicable Sunday or NERC holiday of deUvery. At the , present tim~ Dow Jones define.s the d~livcry schedule for the 24-Hour Index at the Mid-Columbia as twenty-four (24) continuous hours OD Sundays iDd NERC holidays. : '.~ '.. Adjustm~nt" means the $IMWh adjustment to be applied pursuant to the methodology in Section 7.2 and as listed in Table B. Available" means. fOT any hoor, the Centtalia capability of generating electricity up to its rated capacity less amountS due to a Plant ContinaCDCY. 13P An means the Bonneville Power Administration. Ceiling" means the maximum $JMWh quarterly price for energy as applied pursuant to the methodology in Section 7.2 and as 1istcd in Table B. ".- MAY-04-20B0 13: 24 ~"Ej:L TR 403 267 691116 P . 04/23 On-Peak" means the delivery schedule as dermed by ti)e On-Peak ~dex for Monday through Saturday. excluding NERC holidays. On-Peak Index" means the Dow Joncsn.~ Telerate Mid-Columbia Firm On-peak elc.ctricity index for Monday through Saturday. exc1uding NERC holidays, days delivery. At the present time, Dow Jones defines the on-peak dc:.livery schedule faT Mid-Columbia as HE 0700 through HE 2200. Off-Peak" means the delivery schroule as defined by the Off-Peak Index for Monday through SatUrday and the delivery schedule as defined by the 24-Hour Index for Sunday and NatC Holidays. Off-Peak Index" means the Dew Jones TM Tderate Mid-Columbia Fmn Off-peak eleCtricity index for Monday chrough Saturday days of delivery and the 24-Hour Jndex for Sundays and NERC holidays. At the present time, Dew Jones defines the off-peak delivery schedule for Mid-Columbia 1.'1 HE 2300 through HE 0600 for Monday through Saturday. PacifiCorp s System" means the points of interconnection between PaclfiCorp Western control area and the BPA's transmission network such that PacifiCorp is able to import up to the amount being scheduled by TBMUS pursuant to the provisions of Section 10.6. PacifiCoIp s System shan be comprised of the points of delivet)' as shown in Appendix D. Paul" means the point of interconnection betWeen C~ntra1ia and BPA at the SOO kv bus of BPA's Clem\ce W. Paul Substation. PPT" means Pacifi~ prevailing time, wh~ther standard or daylight savings, that is jn effect on any given day. Prime" means the ~imc-weightcd prime interut rate as established by the Morgan ;, . GuarantyTTUStCompanyofNewYork. . . " I' . ' . ' A ' , " Prudent Electrical Industry Practice" means those practices, methods, and equipment. as chang~ from time to time, that; (1) when enpged in are commonly used in pJUdcnt electrical engineering and operations to operate electric equipment lawful1y andwitb safety, reliability, efficiency. and expedition; or (2) in the exercise of reasonable judgment considering the factS known when engaged in, could have been expected to achieve th~ desired result consistent with app~cable law, safety, reliability. efficiency, and expedition. Prudent Electrical Industry Practice is not limited to th~ optimum practice, method, selecdon of equipment, or act, but rather is a range of acceptable practices, methods. selections of equipment. or acts. Plant Contingent" or "Plant Contingency" means an event of Forced Outage or Curtailment that reduces TEMUS's ability to meet its schedules hereunder at Paul for the next schedule hour, provided, TEMUS shan allocate any Curtailment MAY-B4-2800 13:24 m:N:i1=L TA 403 267 69E!6 P .1216/23 maximum monthly load factor of 100%, based on all hours of the month. TEMUS shall be obligated to deliver th~ minimum monthly load factor notwithsW1ding Forced Outage, Curtailment, Maintenance OutageIDerate. or Economic Displacement during such month. Section 5 - DeHvety Point The delivery point for deliveries associated with Section 10. 1 and section 10.2 shall be Paul unless moved to the Mid-Columbia or PacifiCorp s System pursuant to the provisions of Section 10. Section 6 - Creditworthiness The Parties agree to utilizc the creditWorthiness tem1S and conditions pursuant to Section 27 of the WSPP Agreement Section 7 - Contract Price The contraCtual price for all purcbase.o; he~under shan be the summation of Sections 7.1 and 7. (', For the time: period June 1,2001 through June 30, 2002. PacifiCotp shaD pay TEMUS each month a fixed dollar amount per MWh as provided in Table A below for (1501300)% of the energy delivered and received each month. For th~ time period July 1. 2002. through June 30, 2007, PacifiCorp shan pay TEMUS each month a fixed doBar amount per MWh IS provided in Table A below for (250/400)% of the energy delivered and received each month. Month March Year , 2001 2001 2001 2002 29. 2002 21. 2002 43.10 2002 33. 2003 29.55 2003 21. 2003 43. 2003 33. 2004 29. " '\.. "" ~,' .:... " 7' ,.. ' '-.... -. , . March MAY-I1I4-2EJ0121 13: 25 TR~ TF! '41113 267 6906 P . B8/23 Anril, May, June 2003 38.18 14.1.50 July, Aurost, September 2003 61.36.1.50 October, November. December 2003 49.26.1.50 Januarv. February, March 2004 44.72. Ann1. Mav. June 2004 38.15.1.50 JulY. AugUst, SePtember 2004 62.37.1.50 OctOber, November. December 2004 50.27.1.50 Januarv. February. March 2005 44.22.1.50 April. May, June 2OOS 38.15.31 1.50 July. AugUst, September 2005 63.38.1.50 October, November. December 2005 50.21. Januarv, Februarv. March 2006 44.23.1.50 Anril. May, June 2006 38.15.1.50 July. AU2Ust, September 2006 63.38. October. November. December 2006 51.00 27.1.50 JanuarY. F~roary, Marcb 2007 44.23.1.50 Aunl. MI\'. June 2007 38.15.1.50 . - June through September shan be considered a quarter for this time period and adjustments pursuant to Section 12.1 shan taG p1ace on a 4-month quarter. Section 8 - NERC Event Twes The NERC event types referenced herein arc attached as Appendix B. To the extent NERC modifies. ddetcs, or adds new event types. the Parties shall use best efforts to agree upon the catego~atipn of such modified or added event type pursuant to the definitions contained in Appendix B, the intent of the Parties as' of the Effective Dale. BJld the definitions of Curtailment, Forced Outa~ and Maintenance OutagclDerate contained herein. To the extent the Parties are. unable to agree upon the catcgori2:ation of a new or modified event type, the Parties shall utilize the m6p\1te resolution procedures con~ in the WSW Agreement . ~ Section 9 . Loss of Index In the event the On-Peak and/or Off-Pe.ak Index and/or 24-Hour Index is no longer reported. the Parties shall flISt attempt to negotiate a rcp1acement index. In the event a replacement index is not agreed to within 3O-days of the first written offer by either Party. th~ Parties shall then utilize the dispute resolution procedures contained in me WSPP Agreement ~ectlon 10 - Schedulin, 10.To the extent CentraHa is Available, or anticipated to be Available. ,~ ~ rwv:IY-04-200121 13: 26 TR~ TA .41213 267 6996 P. 1121/23 Contingency or the schedule day(s) for which TEMUS has pre-scheduled such Mid- Columbia deliveries to take place. 10.4.1 !EMUS may begin Mid-COlumbia schedules contemplated in Section lOA by giving PacifiCorp no less than 4-hours notice prior to the hour of delivery on the day in which a Forced Outage or Curtailment takes place; provided any such schedules begun pursuant to this Section 10.1 shall continue in the amountS and for the duration of the Forced Outage or Curtailment, and IS otherwise provided for, in Section 10. 10.5 )f TEMUS is able to predict a Maintenance OutagclDcrate 3o-days in advance, TEMUS shall have the option to pre-schedule any portion of its obligation pursuant to Sections 10.1 or 10.2. to PacifiCorp at the Mid-Columbia (rather than at Paul), by 0900 hours PPT on the mutually recognized scheduling day prior to the day(s) of delivery; provided, such schedules shall be firm pursuant to the WSPP Agreement (schedule C2 as amended or replaced) and such schedules shall be for an equal hourly amount for the entire period of Maintenance OutagclDeratc; mPvided further,TEMUS shall notify PacifiCorp s prc-schedulers in writing no less than 3o-days prior to the period in which TEMUS wishes to utilize the provisions of this Section 10.5 and such . ' notification shall include a description of the upcoming Maintenance Ou~ event and its anticipated duration. Schedules pursuant to Sections 10.1 or 10.2 shaD resume on the first schedule day following the end of the Maintenance OutageJDerate event contemplated in this Section 10.5. 10.In the event TEMUS wishes to Economically Displace CentrBlia. ,TEMUS shall have the option to pre-schedule any portion of itS obli&ation pUJ'&uant to Sections 10.1 or 10.2 to PacifiCorp at Paul or PacifiCorp s System. by 0700 hours PPT on the mutually recognized scheduling day prior to the daY(s) of deliVCl)". provided,such schedules shall be finn pursuant to the WSPP Agreement (schedule C2. as amended or replaced) and such schedules for each point of delivery shaD be for an equal hourly amount for either ,the On-Peak or,Oft-Peak bOOfS of the applicable PAy. Schedules pursuant to Sections 10.1 Or 10.2 shall resume on the first schedule day following the end of the Economic Displacement; provided, during the period of Economic Displacement. TEMU5 shan not be precluded from increasing itS Centralia generation level during any given gene-ration hour due to the need to supply operating reserves for itS control area operator under a reserve sharing pool ammgement; provided further, in the event TBMUS wishes to increase the Centralia generation level during any given hour clue to updated market economic situations then TEMUS shan curtail its schedules to PacifiCorp System, no later than 3o.-minutes prior to the hour of delivery. and shalt resume such ~chedules at Paul pursuant to Sections 10.1 and 10.2. In the event TEMUS schedules to PacifiCorp at Paul pursuant to this Seedon 10.6, and BP A denies such schedules at Paul because such generation schedules are not sourced from Centralia, then TEMUS shaD utilize PacifiCoxp s System as the point of delivery. , . " , .. '"",- .." ~ r~~~I:AI 10.Notwithstanding Sections 10.1, 10.2, 10.4, 10.5, or 10.6 the Parties' pre- schedulers or dispatChers may mutUa1ly agree upon delivery hours, delivery rateS, or , pointS of deliv~ry that are different than the provisions of this Confirmation Agreement M=lY-04-21110111 13: 27 TR~ TI=I .403 267 6906 Practice. ~ection 14 - Notices 14.1 An notices and correspondence associated with this Confinna1ion Agreement shaD be sent to the following; To TEMUS:TransA1ta Energy Marketing U.S. Ine. Attention: Legal Department Box 1900, Station 11 1l0-12th Avenue S. Calgary, Albena TIP 2Ml To PacifiCorp:PacifiCorp Sr. Vice Pmiident, power Systems 9951 S.B. Ankeny Street Portland, Oregon 9721&-2315 With a copy to:PacifiCorp Manager. Contract Administration 9951 S.E. Ankeny Street Portland, Oregon 97216-2315 14.TEMUS sha1l contact PacifiCorp s Tea1.time dispatChers as soon as possible fonowing an event of Forced Outage or Curtailment. and as soon as TEMUS able to predict when a Forced Outage or Curtailment may 0CCdf, by calling PacifiCorp real-time desk at 503-251-5222 or 503-251-5224 with an additional notification to PacifiCoxp s pre-schedulers as soon as practicable. TEMUS shall use best reasonable effortS to increase or reduce schedules punuant to the tennS of Sections 10.1 or 10. before 3()..minutes prior to the hour of delivery. Section 15 - Pricing MethodoloEV The pricing contained in Section 7 shall remain in effect through the teml of 1his Confirmation Agreement and neither party sha1l petition the FERC pursuant to the provisions of Section 205 or 206 of the Federal power Act to amend 5ucb prices absent th~ agreement in writing of the other Party. section 16 - Audit Ri2hu PacifiCorp, at its own expense. may rcvi~w TEMUS's accounting records and supportinl documents, including but not limited to the NERC cv~t coding of any cvent(s) associated with Centralia. of any bi11ing associated with this Confirmation Agreement. Pac:ifiCorp shall schcdu1~ such reviews at least fourteen days in advance and at times considered to be normal busincss bours by TEMUS. If either Patty believes there are anyeTTOrs in the detcnnination of a bill, including prices, PacitiCorp shall withhold payment of the disputed amount and the Parties shaH meet to review the accounJ:ing P. 12/23 ~~'",:""-,,;,,. '-f ""'6 -~'~ . . C'" .., MAY-04-2000 13: 27 41113 267 6906TR~~ TA' of the Parties. SeCtion 21 - Countetparts The parties may execute and de1iv~r this Confirmation Agreement by exeCUting a counterpart page hereof and delivering it, whether by facsimile device or otherwise. to the other party and the produCtion of such an executed countelpart page is sufficient for all purposeS of evidencing due execution and de.livery of this Conf1J'II18tion Agreement by a party. Section 22 - Uncontrol1able Force 22.1 In the event that an Uncontrollable Force prevents the generation and delivery of the applicable full contract quantity as specified in Sections 4.1 or 4.2 from Centralia for a continuous period of six (6) months or greater. a) during such initial six-month period. TEMUS shaH only be liable to PacifiCorp for Jiqwdatcd damagcs as provided for in Section 13, without limitation, in amount; b) following such initial six-month period. TEMUS shall only be liable to PacifiCorp for liquidated damages as provided for in Section 13. provided that rEMUS' total net liability for liquidated damages 10 PacifiCorp for such non-delivC1)' dur!ng the period following such initial six-month period shall not exceed U.S. S83.000,OQQJ; and (c) at any time after the cnd of such initial six (6) month penoa.and continuing until the tC-commenc~ment of delivery of the applicable full contract quantity as specified in Sections 4.1 or 4.2 from Ce.ntraJia. PacifiCorp shall have the right to suspend its right and obligation to make power purchases under this Confirmation Agreement without funher liability. ' - , 22.2 In applyjng Section 22.1, the tenn "Uncontrollable Force" shan not include: (a) a Centralia outage related to the installation or testing of pollution contro) equipment: or (b) a curtaihnent of Centralia required by governmental authority as a .\ ~ult of a failure 10 insta11 ~r ~roper1Y operate required pollutiO~ c ~~l devices. , ~--- ( U PM tLe. ~cM((~Ce. wk;v" fcxlkr pjwf-r ~vVr O~/;11tf-;tWlJ ~def fttM CtYJ hrM.q -hHl f1yle~r would f-.nn/'rlii fe; pJ-~ em/l. 14/23 '"L, ~t :"';,;.- t ")0. - --_.~ I"AY -04- 211m 13:28 Sunday Sunday SundaY SundaY ExamPle MonIh . AprIl 2002 TRj;NSA.. TR. Appendix A - Example MonthlY Billing Volume Delivel'8d tMWh1 On.,.1I8k Off-Peek 01-AI:)r-02 4800 1250 Q2-AM-02 4800 2400 os-1I\V0Q2 4800 21400 C*Arwom 4400 OS.Anr-OZ .800 20C00 oe-AIIr-.800 1600 07-Aftr002 NfA 7200 OB-ADr-02 04800 240(1 --' ~OO 2400 4800 2400 4800 1700 12-ADr-02 3000 2400 13-Arv'om 2400 2000 ,..Anr0()2 I\IIA S6OO 1S.Arw-a:O 4800 2400 1 6-AIIM)2 4800 2.00 17-AM-02 ..800 2400 19.A.....m 400 2400 19-ADr-02 "1800 2.&00 2O-Allr-02 41800 2AM 21-Anr.o:!NfA 7200 22.ADr-m 04800 2400 ~Anr.m 4800 2400 !-4-Aftt42 0l1OOO 2000 o68OQ 2400 26-Anr-D'.!4800 2.&00 - . 4800 2400 28oADroO2 tUA '72Ot:I 2DoA11r-G2 4800 2400 SO-A!II'.02 ' ..800 tAOD TOI8I ,,9400 84150 203M0 MWhTot8I Volume Dellverlld undIIr F"1X8d Contnld PrIcII 8OId und8r Indelf ContI1Ic:t Pttae Monthly BUI . Cherges to P8clftCorp 403 267 6906 16/23 \ ", " I: .. ' " )0. (BMed on adU8I delivery VDlumes) (Volume Welghlsd Average mInuS AcIju81m8nl) 11 SQPAWI3OON/W . T oral Volume Deh8nldl (150MW~. ToI8I VoIUI1III Defiv8r'8dJ 135,3tL75 2.206,482.00Charge. tar 1 &OfMJ sold under COIIR18d Index Str\ICIIIr8 . Chargee for 16OMW 8OkI under Axed PrIce 61ruc1U1'8 . Total MontNy ail 541.880. MAY-04-2000 13: 29 TRmSj:L TA.403 267 691216 The other reportable events listed in the table below are In no particular order. Although these events are reponable, they have no reducing impact on the Equivalent Avai1abirJty Factor. Event Description of Other Reportable Events erve hut own - An event that exists whenever a unit Is avaUable fOf load but is not synchronized due to lack of demand. This type of event is sometimes referred to as an economy outage or economy shutdown. If a unit is shut doWn due to any equipment-related problems. whether or not the unit was needed by the system, report an Unplanned (Forced) Outage, Me.intenance Outage, or Planned Outag., n a Reserve Shutdown. Nonc rtalllna Event. An event that exists whenever equipment or major componentS are removed for maintenance, testing, or other purposes that does not result In a unit outs or deratin . . No urtaffina Event - An event that exists whenever a unit Is being intentionally . dispatched at a level less than its full capacity, when the designated capacity would otherwise be at lull ca BC because of lack of demand on the 5 - , 18/23 , " "L. " . ~,..:.. j; ... : '-.., ,..- C' - . . . . Ap p e n d 1 x C er . " " r e l l ' AI o I I I J I " sn n n , . " " " qU l l r f 8 r l J . , . " . u p " o r I n l f l r r p r l c e d arl TJ w n l A I I I t o Pd l C o r p I\ J Qu a r t e r l , Vo l u m e ... . , W ~ t e d Aw r a g e r l f 1 8 In l l i B l Ba s i l DJ M I c l - C 1II 1 1 I a I Pa y m l n l a t M o n t h E n d pa y m e n t a I MI n N y I I I . FI D o r C8 N n g 01 1 C * r i In d C I I Va . . Oa Y ' h M o n l h (C l l c u l l I 1 1 o n M 8 I t I O d ) Ma n l h E n d J. . . . O O $2 2 . 84 3 . $1 . 5 0 $3 2 . 15 0 Ca l 6 . Co 1 T( C d 5- C o 1 4 ) O 24 h l 8 $3 . 40 3 , 11 0 0 Fl b - O ! $2 2 . 5 5 M3 . SU O $5 0 J ) O 15 0 Co l S . Cc I T l C o l 3 1 " 2" " . $4 , 4 1 5 , 04 0 :i t MI r - 0 3 82 2 . 5 5 S4 S , i I O S I . ! O 82 3 . 0 0 16 0 Cd 6 O Co i T( ~ 2) " 2 4 h l l . 52 . 51 9 . 5 9 0 In I I I . , 8\ 1 1 1 1 0 1 Ma n l h l r $1 0 , 33 5 , 4 2 0 QI / a I t e I I y "" ' l a V ' $2 2 . & 5 ~3 . s o $1 . 5 0 $3 4 . 5 0 15 0 Co ! 6 . 00 1 T e e d 5- C o I 4 ) " 2 4 h r s $1 0 89 2 . 0 0 0 Ad d I I o n l l ' n e e o n M e n : h b l l "I M I u p " r I Q u l u t e d y f l o o r t l c e l l l n g 8 $3 5 8 , 51 1 0 'n l e r n l C U I ( b a e d a n R e s u m e d pr t m e r a t e 01 6 5 . . . . . d b1 1 s no r m . . , b e i n g d u e 2 0 d a y t l l l l l ' mo n l l 1 e n d ) J8 I I U I I Y I n t _ l I l t . F e b w l t 1 C l U C I I I n o - $4 , , 8 B 1 , 8o o Ol l l l " n o e 1 0 I n I I I I I pe b b l l . $4 7 3 , 7 8 0 In t 8 f 8 l t d u e M l l 1 d I 2 O I h t o A p d l 2 O l h Fe b r v l l Y I n t l l ' 8 ! l ' S2 . 5 8 Q Ni l M e n : t l ! n v d c e $ 2 , 87 5 . 7 2 8 Au n : l d S e t t l - ~ nd l l I I O I I I h w i U l i e b - e d l i l t D o w 'C l l l t S d 8 1 I J In d d . . . q e l O W l ' II I G I I I b . I f m O 1 l 1 1 l f y IY C r q e 1 I I b I . . bu k 4 I t c u m d 8 l o e e l l l D o o r o r a: l U n l w I - . l 1 8 m l l 8 l l l l y p y m a t t f n m I Pl e I I l C o l l l t a Tt l D l A l t i w i n . . . s j n t e d CI I I - l n l t l l l b a l a l D f t f I K t . . . n - CI r 1 I I I J I R t . Aa ' t b . . . . . o f a c b q u u w , "' _ l h I y M l wl l l l K l u d e . " 1 n I n l u p " ; w h m b y d l l q u l t l l : l l J a Y e n l e o f t b c D i l l y J ) o w JD M 8 h u ' a , l i e e s .. . . . . b_ I , 1 i 1 t ' J l l l l l l l w i n b e r c I I I I P I f I I I t o ft a o r .. a l l \ l l l w I J e t . T o 1 h 8 . 1 1 n 1 0 . . . Il l l l l d U f t I l d j l l l f n I 8 I I I l J I I I f e a a _ i n i t i a l b i l l " _I I D I J e I l I I I r e d .. . . . v l l J W l I I on . q t W t a l y " u t i a c r e d i t o r , , ; o m a l l 'I0 I l 0 -- DO t l 8 1 . . l I o n d I ! r 11 1 1 1 I I I f I d I ~ , "" ' . m d h la r " ' i o I I o r It / M l l w i U k- hI n * ' d m e a f - l l l l D l l l h \ y IP I ) ' m a I I J _l 4 l 1 e d d o u n l i t di e ." ' " ,a y m e t a wl U - d u e . "t J 11 : 1 ' ' , ' " ) . L: t )' " .' . . ' MAY-04-2000 13: TR~ 403 267 6906 ~rmation Agfcement 22/23 , '"';'.~ ,. OUTLOOK POINT OF DELIVERY Location: the point in PacifiCorp s Outlook substation where the 230 kV facUitics of the parties heretO arc connected; Voltage: 230 kV. Metering: in PacifiCotp s Out\ookSubstatioD, in the 115 kV circuit over which eleCtric power and energy flows; Exception: there shall be an adjustment for losses between the point of metering and the point of delivery; PILOT BUTTE' POINT OF DEUVERY Location: the point in BPA's Rcdmond- Yamsay 230 kV tranSmission line where the facilities of the Parties hereto are connected;. Vol~:230kV; Metering: in PacifiCorp's Pilot Butte Substation, in the 69 kV circuit over which elc.ctric power and energy flows. Exception: there shall be an adjustment for losses betWeen the point of metering and the pOint of delivery-. PONDEROSA pOINT OF DELIVERY Location: the pointin BP A's Pondcrosa Substation w.he~ the 230 kV facilities of the . \ .. " ' Partics,heretoareconnCcfed. ' ,!" . ~.,.. ,~ ". . ~'I. Voltage: 230 kV; Meterinl: iIi BP A 's Ponderosa Substation. in the 230 kV circuit over which electric power and energy flows; RESTON pOINT OF DELIVERY Location: the point in BfA's RestoD Switching Station where the 230 kV facilities of the Parties hereto are conncctccl; Voltale: 230 kV; Meterinc: in BP A 's Resten Switching Station. in the 230 kV circuit over which electric power and energy flows; LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Appendix A Appendix B Appendix C Appendix D Appendix E Appendix F Annual Variable Cose A-1 Resource Pool . B-1 Service Schedule D to ehe TEP Interconneceion Agreemene C-1 Service Schedule E to the TEP Interconnection Agreement . D-1 Power Exchange Examples . E-1 Example Calculation Establishing Adj usemenes for Interese . F-1 ,.- Redding" "(Original Agreement") which provided for PacifiCorp to sell SO megawatts of capacity and associated energy to Redding for twenty years from June 1, 1994 through May 31, 2014, subject to certain termination rights. Insofar as a portion of the capacity and associated energy that would be purchased by Redding would be in excess of Redding I S needs, with such portion declining over t:.me. Redding entered into a "Contract for Purchase of Power and Provision of Services" with the United States of America, Department of Energy, Western Area Power Administration ("Western" ) pursuant to which Western would purchase the portion of capacity and associated energy which Redding purchased from PacifiCorp and which was in excess of Redding I s needs.The term of Redding I s agreement with Western is coterminous with the term of the Original Agreement, subject to certain termination rights. Redding is a member of the M-S-R Public Power Agency ("M-S-R"), a joint powers agency duly organized under the laws of the Sta~e of California and consisting of the Modesto Irrigation District, the City of Santa Clara, and the City of Redding. M-S-R is a party to an agreement with the Bonneville Power Administration ("BPA") dated October 31, 1989, under which, among other things, M-S-R currently purchases 100 megawatts of capacity and associated energy from BPA. has a 1St interest in this agreement. Redding Page 2 -LONG- TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING Because of seasonal di versi ty in their loads, Redding and PacifiCorp would benefit from a new contractual arrangement that would provide for a seasonal exchange of capaci ty and energy while accommodating existing contractual arrangements. Aareement The Parties agree to the terms and conditions set forth herein. Definitions As used herein, the following terms have the following meanings when used with initial capitalization, whether singular or plural: \...; Additional Energy" means the sum of available Winter Energy and available Short-Fall Energy, both of which are defined below. Agreement" means this Agreement between Redding and PacifiCorp, including Appendices A, B, C, D, E and F, which are attached hereto and made part of this Agreement. Annual Variable Cost" means, in any calendar year, the weighted variable cost expressed in dollars per megawatt- hour ($/MWh), as determined by the methodology set forth in Appendix A, of the resources contained in the Resource Pool in such calendar y~ar, with such costs of new resources, if any, Page 4 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING \...; Firm Energy" means the energy associated with Firm Capacity. Maximum Entitlement" means Redding's 4.32 percent entitlement (15 percent of M-S-R's 28.8 percent entitlement) to San Juan Uni t 4 energy product ion. Northwest A. C. Intertie" means the 500 -kV transmission facilities or portion of transmission facilities in Oregon as described in the Northwest lntertie Agreements, such agreements being the agreements between and among BPA, PacifiCorp, and Portland General Electric (Northwest Participants) and any amendments thereto, which among other things, set forth the Northwest Participants' rights and obligations between and among themselves with respect to the Northwest A. C. Intertie and associated facilities, identified as the BPA-PacifiCorp Contract No. DE-MS79-94332 and associated agreements and the SPA-Portland General Electric Contract No. DE-MS79-87BP92340 and associated agreements. Off-Peak Hours" means the hour ending 2300 through the hour ending 0600 Pacific Time, Monday through Saturday, all hours on Sunday, and the holidays of New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day. Point of Delivery" means, for all deliveries of Firm Capacity and associated Firm Energy from PacifiCorp to Redding, points on PacifiCorp' s system as mutually agreed upon Page 6 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING "Short-Fall Energy" means amounts by which Redding schedules Seasonal Energy below 20 megawatt-hours in any hour as provided for in Sections 9.4 (a) and 10. "Winter Energy" means energy available to Redding equal to' the amount of energy from San Juan that PacifiCorp schedules in excess of 12,000 megawatt-hours in any month of a Contract Year. Term and Termination Effective Date and Termination Date This Agreement shall be effective following its execution by both Parties and upon its acceptance for filing, as provided in Section 5. Service shall commence at the hour ending 0100 on the first day of the month following acceptance for filing by the Federal Energy Regulatory Commission ("FERC""Service Commencement Date") which t~e Parties anticipate will occur on or before February 29, 1996.Except as provided in the termination options set forth in Sections 5.2 and 16, and except as to allow for the delivery of Exchange Energy to Redding (if any) pursuant to Section 9.6 through 2016, this Agreement shall terminate at 2400 hours, November 30, 2015. Reaulatorv ~DDroval PacifiCorp shall file this Agreement with the FERC in a timely manner subsequent to its execution.PacifiCorp shall provide Redding with a copy of the filing prior to submittal to the FERC and Redding shall file Page 8 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING MaximumAmount of Reduct ion December 1, 1995 through May 31, 1996June 1, 1996 through May 31, 1997June 1, 1997 through May 31, 1998June 1, 1998 through May 31, 1999June 1, 1999 through May 31, 2000June 1, 2000 through November 30, 2000 35 MW 30 MW 25 MW 15 MW 5 MW 0 MW The Firm Energy delivery provisions pursuant to Section 7 shall apply to the reduced level of Firm Capacity.Redding may elect such reduction by giving PacifiCorp 30 days advance written notice prior to the effective date of the reduction and the reduction shall continue for not less than 12 consecutive months.Any reduction in Firm Capacity and associated Firm Energy shall be considered "Undelivered Power" and shall result in the adj ustment set forth in Section 8. Firm Enerav Deliverv Provisions Beginning on the Service Commencement Date and continuing through November 30, 2000, PacifiCorp shall deliver Firm Energy associated with Firm Capacity at load factors, as scheduled by Redding, not to exceed 100 percent per hour, 100 percent per month, and 85 percent per Contract Year.Redding shall purchase such Firm Energy at load factors of not less than 70 percent per month, and 85 percent per partial Contract Year or full Contract Year. Page 10 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING billing purposes in the remaining billing periods for such Contract Year.To the extent such estimates result in payments for Firm Energy en a Contract Year basis that differ from Redding I s obligation to pay as stated in Section 8.:2, the Parties shall reconcile such differences pursuant to Section 11.:2. Undelivered Power Adiustment In the event of Undelivered Power, Redding I s continuing obligation to pay shall be as follows: Redding shall pay the price set forth in Section 8.1 for 50 megawatts of Firm Capacity. Redding shall pay or receive a credit each month for Undelivered Power as set forth below: Monthly Adjustment (in ($) = REx(M - EAVC) /2, where: R~ x 730 hours x LF, where R~=Reduction inFirm Capacity (MW) and LF = energy loadfactor during such month Index of the arithmetic average of the weekly spot electricity prices during such month at the California-Oregon border as published in McGraw-HilI'" Power MarketsWeek" . (Example: Index for week ending November 17, 1995=$14. OO/MWh. SeePower Markets Week publication dated November 20, 1995). the Estimated Annual Variable Cost ($/MWh)specified in Section 8. If the adjustment is a negative number, such amount shall be EAVC= added to Redding's bill for such month.Conversely, if the Page 12 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING combination of Redding I s Maximum Entitlement to Unit 4 Power and Redding I s rights under Appendix D to this Agreement, provided that, if Redding I s rights to San Juan Power are reduced during San Juan unit outages, PacifiCorp I s rights to Power under this Agreement shall be reduced to the amount available to Redding under Appendix D to this Agreement. 1.2 Reddinql s Riahts to San Juan Power the extent, in any given hour, PacifiCorp does not exercise its full rights under Section 9.1 of this Agreement, together with associated transmission delivery rights, Redding shall have the right to schedule for its own account capacity (and associated energy) equal to the difference between the maximum amount of San Juan Power made available pursuant to Section 9 .2 . 1 . 1 in a given hour and the amount of San Juan Power that is being scheduled by PacifiCorp for that hour; provided however, Redding I s rights shall at all times be subordinate to PacifiCorp I S prescheduling and real-time scheduling rights from San Juan. 1.3 Minimum Deliverv Obliaations During each hour during which San Juan Unit 4 is operating, PacifiCorp shall have the obligation to take delivery of a minimum of the lesser of Redding I s share of the San Juan minimum hourly output or 9 megawatt-hours per hour.During times when Unit 4 is unavailable, this obligation shall become zero.During each Contract Year, PacifiCorp shall have the obligation to take Page 14 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING Minimum Hourly and Monthly Deliveries Redding shall have no obligation to take delivery of Power in any hour but shall have the obligation to take deli very of at least 16,250 megawatt-hours in each month. Maximum Hourly and Monthly Deliveries Redding shall have the right to take delivery of 50 megawatt- hours in each hour and 27 500 megawatt-hours in each month. Maximum Seasonal Deliveries During each Season, Redding shall have the right to take delivery of an amount of Seasonal Energy. the following circumstance: Such amount shall be reduced in If, for any hour during a Season, Redding schedules less than 20 megawatt-hours, the amount of the short-fall below 20 megawatt-hours ("Short-Fall Energy"), shall accrue as Additional Energy pursuant to Section 6); provided, however, for such hour, 20 megawatt- hours shall be subtracted from Seasonal Energy and the annual minimum deli very obligation pursuant to Section Chanaes in San Juan Enerav Availabili tv If San Juan Unit 4 is permanently rerated such that the hourly energy available pursuant to the Maximum Entitlement is more or less than 21.5 megawatt-hours, the numerical limits set forth in Sections 9.2 and 9.4 and the number "27,500" in Section 9.3 shall be correspondingly Page 16 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING (ii) on a nonfirm basis during the months of December, January and February during hours as mutually agreed by the Parties; or (b)Subj ect to the provisions of Section 10. Redding may take delivery of 75 percent of any accumulated Additional Energy on a firm basis during Off-Peak Hours during the months of December through April and November, with the corresponding 25 percent of accumulated Additional Energy being forfeited. Prior to November 1 of each Contract Year during the Exchange Period, Redding shall provide PacifiCorp with written notice of which of the aforementioned Additional Energy delivery options it has selected for the ensuing Contract Year. Exchanae Conversion Oct ion If, during any consecutive 24-month period, energy from San Juan is not available to PacifiCorp for a cumulative total of 4,380 hours, for any reason, upon providing Redding with 60 days advanced written notice, PacifiCorp may elect to convert the delivery of San Juan Power to San Juan Alternate Power.Within such 60 day notice period, Redding may elect to procure San Juan Alternate Power from a third party; provided, however, that PacifiCorp shall have right-of-first-refusal to provide such San Juan Alternate Power at the purchase price quoted to Redding for such San Juan Alternate Power.I f Redding does not procure San Juan Alternate Power, PacifiCorp shall be obligated to provide Page 18 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING subsequent peak load (s) .In no event shall PacifiCorp be liable to any party in connection with any impairment or loss of the tax-exempt status of bonds issued by M-S-R in connection with San Juan, and Redding shall indemnify and hold PacifiCorp harmless in regard to any claim associated with any such impairment or loss. 10.Schedulina 10.Preschedules of Enerav bv Reddinq Redding shall preschedule (by telephone unless otherwise agreed by the Parties I schedulers) deliveries of Firm Energy, Exchange Energy and Additional Energy from PacifiCorp no later than 1000 hours Pacific Time on each work day observed by both Parties immediately preceding the day or days on which such energy is to be delivered, or as mutually agreed by the Parties dispatchers or schedulers.PacifiCorp shall deliver in accordance with those preschedules which comply with the delivery obligations specified in Sections 7, 9 and 10. the event of changes in Redding I s system between the time of preschedule and the actual schedule hour, due to significant changes in resources andl or loads, Redding may request a change in preschedule with no less than a two and one-half hour notice prior to the hour of delivery, and PacifiCorp shall make best efforts to accommodate such changes in Redding I S pre schedules. Page 20 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING If Redding has elected the Additional Energy delivery option set forth in Section 9.7(b), the Maximum Hourly Rate of Delivery (stated in megawatt-hours and rounded to the nearest megawatt-hour) shall equal the result of the following equation: 5 x M = Maximum Hourly Rate of310 Off-Peak Hours per month Delivery (megawatt-hours) Where:Maximum Monthly Rate of Delivery calculated above Provided, however the Maximum Hourly Rate of Delivery of Additional Energy shall in no event be less than 5 megawact- hours per hour nor greater than 50 megawatts per hour. 10.No CarrY Forward Redding shall not be obligated to schedule any minimum amount of Additional Energy. Except provided for in Section 9.6, any amounts accumulated prior to the Season of the current Contract Year and not scheduled during such Contract Year shall not be carried forward to any future Contract Year. 10.Schedulinq of San Juan Enerav bv PacifiCorD November 10 of each Contract Year during the Exchange Period, PacifiCorp shall furnish Redding with a nonbinding estimate showing PacifiCorp I s anticipated monthly schedule of San Juan energy for the following Contract Year.By the 23rd day of each month, PacifiCorp shall furnish Redding with a nonbinding estimate for the following month of expected hourly deliveries of San Juan energy.Such estimate may be in the form of a (', Page 22 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING 10.Schedule Curtailments 10.Curtailments of Deliveries At times when PacifiCorp is unable to deliver or Redding is unable to receive deliveries of energy hereunder as a result of the Western Area Power Administration's inability to receive deliveries of energy from Redding due to curtailments by Pacific Gas and Electric Company (PG&E) for low load conditions in the PG&E service area, or a curtailment of schedules on the Pacific Northwest/Pacific Southwest A. C. Intertie due to loop flow or line outages, Redding shall be relieved of its obligation to accept such energy and PacifiCorp shall be relieved of it8 obligation to provide energy during those hours of curtailment conditions.The Parties shall use best efforts to estimate the hours of such curtailments and submit such estimates in a timely fashion.Any energy interrupted hereunder shall be rescheduled in amounts and at times as mutually agreed by the Parties' schedulers and dispatchers. 10.Precedence of M-S-R Resources The Parties agree that if transmission schedules on the Pacific Northwest/Pacific Southwest A. C. Intertie are curtailed, Redding's M-S-R/BPA resource shall take precedent.That i8, if transmission curtailments are required, Redding's share of such curtailments shall be met first by reducing its deliveries under this Agreement; provided, however, with respect to curtailments, that deliveries under this Agreement shall take Page 24 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING 11.2 Annual Adiustments Prior to the September of each of the calendar years 1997 through 2001, utilizing the FERC Form 1 data upon which the Annual Variable Cost is based, PacifiCorp shall determine Redding I s payment obligation for the Contract Year ending November 30, nine months prior to such September based on the prices determined in accordance with Section 8.2 and applied to Firm Energy pursuant to Section In the event the amount so determined is greater than the amount actually paid by Redding pursuant to Section 11. PacifiCorp shall add the amount of such difference, as adjusted for interest pursuant to Appendix F, to the September invoice of said year.In the event the amount so determined is less than the amount actually paid by Redding pursuant to Section 11.1, PacifiCorp shall subtract the amount of such difference, as adjusted for interest pursuant to Appendix F, from the September invoice of said year; provided, that, if such amount to be subtracted is greater than the September invoice amount, PacifiCorp shall promptly pay to Redding the difference between such amount and the September invoice amount.However, if the difference is greater than ten percent of the total annual payment obligation associated with the Contract Year being adjusted for, then either party may elect to spread the payment associated with such difference over a twelve month period commencing with the September invoice of said year with Page 26 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING 12.Cost Determination Chanqes The cost methodologies utilized for pricing purposes in this Agreement and the pricing formulae specified herein shall remain in effect through the term of this Agreement, and neither Party shall petition the FERC pursuant to the provisions of section 205 or 206 of the Federal Power Act to amend such methodologies or formulae, or support such a petition by any other person or entity, absent agreement in writing from the other Party. 13.Audi t Riqhts 13.Reddinq' s Audit Riqhts Redding, at its expense, shall have the right to audit and to examine any cost, payment, settlement or supporting documentation related to any item set forth in this Agreement.Any such audit shall be undertaken by Redding or its representatives at reasonable times and in conformance with generally accepted auditing standards.The right to audit a cost shall extend for a period of five years following the billing for such cost under this Agreement. PacifiCorp fully agrees to cooperate with such audit and to retain all necessary records or documentation for the entire length of the audit period.Redding shall take all steps reasonably available to secure the confidentiality of PacifiCorp I S accounting records and supporting documents. Page 28 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING To Redding: Elec~ric Utili~y Direc~or City of Redding 760 Parkview Avenue Redding, California 96001-3396 wi ~h a copy to: Ci ty Manager Ci ty of Redding 760 Parkview Avenue Redding, California 96001-3396 To PacifiCorp: Vice Presiden~, Power Systems and DevelopmentPacifiCorp 825 NE Mul~nomah, Suite 485Por~land. Oregon 97232-4116 wi~h a copy ~o: Manager Cus~omer Con~rac~ Adminis~ra~ion PacifiCorp 825 NE Mul~nomah, Suite 625Por~land. Oregon 97232-4116 The Par~ies may change a~ any ~ime ~he persons to whom notices are addressed, or ~heir addresses, by providing no~ice ~hereof as specified in ~his Sec~ion 14. 15.Uncontrollable Forces Neither Par~y ~o this Agreemen~ shall be considered to be in default in performance of any obliga~ion hereunder if failure of performance shall be due to an Uncon~rollable Force. The ~erm "Uncontrollable Force" means any cause beyond the con~rol of the Party affected. including, but not limited to, failure of facilities, flood, ~sunami. earthquake. storm, fire, Page 30 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING lightning, epidemic, war, riot, civil disturbance, labor disturbance, sabotage, and restraint by court order or public authority, which by exercise of due foresight such Party could not reasonably have been expected to avoid, and to the extent that by exercise of due diligence it shall not have been able to overcome.A Party shall not, however, be relieved of liability for failure of performance to the extent such failure is due to causes arising out of its own negligence or to the extent such failure is the result of removable or remediable causes which it fails to remove or remedy with reasonable dispatch.Any Party rendered unable to fulfill any obligation by reason of an Uncontrollable Force shall exercise due diligence to remove such inability with all reasonable dispatch and shall notify the other Party of such Uncontrollable Force as soon as practicable.Nothing contained herein, however, shall be construed to require a Party to prevent or settle a strike against its will. 16.Reaulatorv Imcact In the event that the FERC or any agency or court of competent jurisdiction materially modifies any term or condition of this Agreement in such a manner that either Party is required to incur new or different obligations not expressly provided herein, the Parties shall attempt in good faith to renegotiate the terms and conditions of this Agreement so as to Page 31 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING harmless the First Party from, such liability.As used in this Section,( 1) the term Party" means, in addition to such Party itself, its directors, City Council members, officers, and employees;(2) the term "damage" means all damage, including consequential damage; and (3) the term "person" means any person, including those not connected with either Party to this Agreement. 19.DisDute Resolution The Parties shall make best efforts to settle all disputes arising under this Agreement as a matter of normal business and without recourse to litigation.Pending resolution of a disputed matter, the Parties shall continue performance of their respective obligations pursuant to this Agreement. l,; 20.Amendments This Agreement may be amended only by a written document signed by both Parties hereto. 21.Assianabili ty This Agreement shall not be assigned without the prior written consent of the Parties, which consent shall not be unreasonably withheld, provided , however, that this Agreement may be assigned without prior consent to the following: Page 33 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING IN WITNESS WHEREOF, the Parties hereto have caused this Agreement :~ be exec~ted in their respective names by their respective officers thereunder duly authorized. (SEAL) B .Address: 760 Parkview Avenue Title: Assistant Redding CA 96001 (, I /J IlN.. " o,J ~i J By: Ti tle: Address:700 N. E. Multnomah, Suite 1600 Portland, OR 97232 Page 35 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING ection A2:Determination of ColstriD Pro;ect Annual Variable ost Jim Bridaer Pro; ect Annual Variable ost Hunter Pro ect Annual Variab Cost and Hunter Pro; ect Annual Variable Cost The Colstrip Projec~ Annual Variable Cost, the Jim Bridger Project Annual Variable Cost. the Hunter #2 Project Annual Variable Cost and the Hunter #3 proj ect Annual Variable Cost shall be determined. for each Project. by (a) adding the amounts as set forth in Sections A2.1 through A2. (plus A2. 3 for Hunter #2 and plus A2. 4 for Hunter #3) and (b) dividing each Project total by PacifiCorp's share of the associated Project's annual energy production as filed with the Federal Energy Regulatory Commission (FERC) in PacifiCorp's FERC Form No.1. or its successor thereto. Production Expenses shall be equal to the production expenses of resources in the Resource Pool "as filed in PacifiCorp's FERC Form No.1, or its successor thereto. A2.In lieu of payments shall consist of any assessment, payment in lieu of taxes or other charge which is imposed against ?acifiCorp by governmental authority and related to the operation and maintenance of each proj ect. A2.Hunter #2 proj ect allocated mining expenses, to be determined by adding the amounts calculated under Sections A2. 3. through A2. 3 . 4 below: A2.PacifiCorp's adjusted initial levelized annual fixed charge rate for the Hunter #2 project mining investment multiplied by the Hunter #2 project mining initial investment, Appendix A - 2 amount equal to t~e produc~ of 1) the quotient of to~al PacifiCorp ad~inistra~~ve and general expenses to total PacifiCorp electric plant in service; and 2) the total Hunter #2 proj ect mining inves tmen t A2.Hunter #3 proj ect allocated mining expenses, to be determined by adding the amounts calculated under Section A2. 4. through A2. 4.4 below: A2.PacifiCorp I S adjusted initial levelized annual fixed charge rate for the Hunter #3 Project mining investment multiplied by the Hunter #3 Project mining initial investment, determined pursuant to Section A3, as of December 31,1990.For purposes of this section, PacifiCorp' s total investment in Hunter #3 project ~ining is $44,588,747.Such total investment shall remain constant through the book life (14 years) and shall be $0 af terwards .Such adjusted initial levelized annual fixed charge rate shall be determined by subtracting book depreciation (llbook life) from PacifiCorp I s initial levelized annual fixed charge rate for the Hunter #3 project mining investment determined annually in accordance with Section A4, below. Such book depreciation is reflected in Hunter #3 fuel cost. A2.Each subsequent annual levelized fixed charge shall be determined by multiplying (a) PacifiCorp's subsequent levelized annual fixed charge rate for the Hunter #3 Project mining investment, as calculated in accordance with Section A4, below, by (b) the dollar investment in capital additions, replacements (less credit for net salvage and insurance proceeds, Appendix A - 4 (-- ~~e ratio or Paci:~Corp I s share of the associated Projects capab:li~y (235 w~ fc= H~n~er #2 Project and 400 MW for Hunter #3 ?roj ect) di videa =y ~te : ~~a: ca~ab::i:y 0: a:: ?=~~€C~s served by the mines (presently 1995 MW) Gross coal plant, as reported in FERC account 399 as Total Other Tangible Property" in PacifiCorp' s FERC Form 1 as of December 31, 1990. Each subsequent coal m1ne investment in capital additions, replacements (less credit for net salvage and insurance proceeds, if any), and betterments, as determined pursuant to data contain in PacifiCorp I s FERC Form 1 or its successor thereto. Section A4:eme Hunt r #and unte Pro; ect Minina estment elized Annual Fixed Charae Rates A4.Cacital ctu A4 .For purposes of calculating initial levelized annual : ~xed charge rates. ?acifiCorp I s capital structure will rema~n constant.~he capital structure for Hunter #2 and Hunter #3 Project is: Long Term Debt 50% 10%Preferred Stock Common Stock Equity ':'otal 100% A4 . 1. PacifiCorp I S capital structure will remain constant for purposes of calculating subsequent levelized annual Appendix A - 6 \..-, \...I \..,I levelized annual :ixed charge rate is calculated.In the event there are ~o bond issues within the said twelve (12) -month period. then an esti~ated =~nd interest rate will be used i~ ::~e til~ings. based upon the bond =ating then applicable to PacifiCorp until such time as there is a bond issue. at which time all future billings will reflect the actual cost to PacifiCorp of such bond ~ssue .In the event such bond issue is subsequently exchanged for other bonds. the new bond rate shall be used for subsequent billings. A4 . 2 . Preferred Stock Return on preferred stock applicable in the calculation of each initial levelized annual fixed charge rate shall be eight and twenty-four hundredths (8.24%) .Return on preferred stock applicable in the calculation of subsequent levelized annual fixed charge rates for future capital additions. replacements. or betterments shall be the same as for bond interest used in calculation of subsequent annual fixed charge rate. plus fifty (50) basis points. A4 . 2 Common Stock Eaui For pricing purposes only the component for the rate of ROE applicable in the calculation of the initial levelized annual fixed charge rate and each subsequent levelized annual fixed charge rate for any calendar year shall be equal to PacifiCorp I s then-effective rate of ROE which has been authorized by the FERC. PacifiCorp shall use a rate of ROE of eleven and seventy-hundredths percent (11.70%) as authorized for use by FERC in FERC :Jacket No. ER-93 -052-000. PacifiCorp shall make a timely Appendix A - 8 --- which Paci:iCorp provides re~ail serv~ce. A4 . 4 . 3 ~he Modified Accelera~ed Cos~ Recovery Sys~ern (modified ACRS) me~hod of tax depreciation in accordance wi~h the ~ax reform ac~ of :986 shall be used in calcula~ing bo~h the ini~ial and subsequent levelized annual fixed charge ra~es. A4 Regular Inves~rnent Tax Credits allowed in accordance with the provisions of the Internal Revenue Code of 1954, as amended, regardless of whether PacifiCorp is able to use such credits shall be used when calculating subsequent levelized annual fixed charge rates. A4 4 . 5 ~ax basis shall be one hundred percen~ (100%) of the book basis in calcula~ing each ini~ial levelized annual fixed charge rate and one hundred percent (100%) of the book basis in calculating each subsequent levelized annual fixed charge rate. Appendix A - 10 ( )- " Jim Bridger Proj ect Annual Variable Cost (Based on 1990 FERC Form Product:on Exoenses Operation, Supervision and Engineering $ 1,906,989 110,073,590Fuel Stearn Expense 378,692 924,875Electric Expense Misc. Steam Power Expenses 996,408 36,080Rents Maintenance. Supervision and Engineering 402,476 296,637Maintenance of Structures Maintenance of Boiler Plant 12,060,367 361,026Mai~tenance of Electric Plant Maintenance of Misc. Steam Plant 458,585 --------- Sub-Total $143,895,725 :n Lieu 0: Payments 7otal Variable Costs Jim Bridger Project $143,895,725 727,673Annual Energy Production (MWh) Jim Bridger Annual Variable Cost $14.79 /MWh ------------------ Appendix A - 12 Hunter Proj ect Annual variable Cost (Based on 1990 FERC Form Production Exoenses Operation, Supervision and Engineering Fuel Steam Expenses Electric Expense Misc. Steam Power Expenses Rents Maintenance. Supervision and Engineering Maintenance of Structures Maintenance of Boiler Plant Maintenance of Electric Plant Maintenance of Misc. Steam Plant Sub-Total Allocated :'!ining Expenses :n Lieu of Payments Total Variable Costs Hunter #3 Project Annual Energy Production (MWh) Hunter #3 Project Annual Variable Cost * See Attached sheet A-18 for details Appendix A - 14 562,579 26,295,191 281,882 277,460 1, 199,505 254 855,461 575,125 026,339 243,417 111,556 --------- $35,429,769 $3,745,023 $39,174,792 348,751 $11.70 IMWh ------------------ HUNTER #2 AND #3 MINING INVES'l'MENT ALLOCATION CALCULATION Gross Coal Plant (=E~C F .l-?g 207a)5222,386,377 Power Plants served by Mines:~OJ Huntington # Huntington # Hunter #1 UPL Hunter # 1 Provo Hunter #2 UPL Hunter #2 DG&T Hunter #3 UPL 400 415 366 235 155 400 Total:1995 Hunter #2 Mining Investment = 235/1995 x $222,386,377 = $26,195,889 Hunter #3 Mining Investment = 400/1995 x $222,386,377 = $44,588,747 Appendix A - 16 HUNTER #3 PROJECT ALLOCATEDMINING EXPENSE CALCULATION (Based on 1990 Actual Costs) Initial Levelized ~~nual Fixed Charae Hunter # 3 Pro; ect Hunter #3 Mining Investment S44,588,747 Adjusted Initial Leve1ized Annual Fixed Rate 551% Ini tial Levelized Annual Fixed Charge Subsequent Investment S2, 921. 009 Subsequent Leve1ized Annual Fixed Rate Subsequent Leve1ized Annual Fixed Charge Ad Valorem Tax Taxes, assessments and in lieu of taxes Administration & General Expenses: :990 ~otal PacifiCorp A & G Expense = S145, 713,1901990 Total PacifiCorp Electric Plant In Service = $7,884, 778,137 A & G Expense as a percent of Investment = 1.85% Hunter #3 A & G Expense = 5824.014 Total $3,745,023 * See attached sheet A-16 for details. Appendix A - 18 HUNTER #2 AND #3 MI:NE INVESTMEN'l'FORMULAS FOR CALCULATINGINITIAL LEVELIZED FI:XED CHARGE RATE (Sample Calculations based on Year 1 and shown rounded to nearestwhole dollar) 1) CAPITAL RECmlERY FACTOR, (CRF) = i (1+i)n/ (1+i)n -1Where i weighted cost of capital and n = ave.life of plant. CRF = 0.0974(1 + 0.0974) 14/((113382 0974) 14 - 1) (*2) BOOK DEPRECIATION = $100,000/14 Years $7 , 143 ( * 3) TOTAL RETURN,(TR) Where A = A x Ws = Average Net Investment; and = Weighted Cost of Preferred and Conunon StockLet A = Beginning Investment - (D+T) /2, vfuere Beginning Investment = Previous year I s beginninginvestment - previous year I s D and T. = Book Depreciation (*2)= Deferred Tax (*5)Therefore. beginning investment = $100,000 = $100,000 - (7,143 + 2631) /2 =$95,113TR = $95,113 x (.10 x .0824 + .40 x1170) = $5,235 ( * 4 ) INTEREST, ( !) A X Wd~fuere Wd = Weighted Cost of Debt Therefore. I = $95,113 x (.50 x .0847) =$4,028 5) DEFERRED TAX. (T) Where To TR Let T = (To -D) x TR Tax Depreciation (*8) Tax Rate (36.81%) (14,290 - 7,143) x .3681 =$2,631 .-' Appendix A - 20 APPENDIX B RESOURCE POOL This Appendix sees forth the amount of capacity (MW) and ehe combination of resources which may be included in ehe Resource Pool which shall be the basis for determining the prices for Firm Energy under Section 8. During the period June 1, 1996 through November 30, 2000, the Resource Pool shall contain 800 megawatts of capacity consisting of the following combination of resources: Total Capaci ty .wID. 235 iQQ 800 MW Resource Colserip Project Jim Bridger Project Hunter No.2 proj ect Hunter No.3 proj ect Provided , that commencing June 1, 2000, and continuing through the the Contract Year ending November 30, 2000, PacifiCorp may replace up to a maximum of 100 megawatts of resources and associated coses in the then-exiseing Resource Pool with other cost resources: i. e., in the Contract Year ending November 30, 2000 the Resource Pool shall contain a minimum of 700 megawatts of resources that were included in the Resource Pool in the Contract Year ending November 30, 1996. Appendix B :JO. 1 =0. : =0. DO. =0. : APPENDIX C ,.--- --......-----... -- --.. ,-...--, .. .::..:. ---,."':'- - --.... ~~:.'::",::"...':'., .. betwe~:::-::c::=:: ~:.:::":'~:C ?QWE:. C:=:.1?A.N" and ?" ?U=.1.:C: ?OWEE. .~CZNC"'" !:VI~~ S~:R "":C:E: SC~:E:~U!.::: 1:) ?o'\v=:? ==:':=~.A. NCE ACi?==~M!:N7 1."his Ser"""c:e Sc:::.ecule D is agreec upcn as pa.:: of the !::.:erc:::.::.ec:=:: .-\ gr eeC"..e:1t e:tereci i::o between :-::CZON ::::.z=,:,~..:= ?OW!::R. C=~Y!P.A,.NY (""!";:=soc,) a.:d M .A ?U1!UC POW -- -~'-" ft" .:...:.. ."\~':"" .n- -~ it!: Co... ::A.I..S Tucson cwus .n 0;:-"'::::' to a.c:;,::i:e a.:u::.c.i-riciec Zg. S pe~c:eA: i::erest ~ :':'e San .Juan Gcncr:Ui::.g Station U:i: No. -i: ("$a.: JU6Z1 4'" a.no ?lans :0 C:=:::::l:: := sell said ope:::. :0 M -5- A. ?, i::er.c.s to exerc::.se t!:e Opt:':: and become a.a. OWft.er a.s a tena.z:.: ~ =::-"_ '"'::n 0: San Juan 4- eUec:ive on May 1 . 1995. a desires to rec:eive Qe energy ou:;:ut fr:::". its owner- ship i::.terest i::. San .Juan 4- a.t :::'e ?a..lo Verde Nuclear GeaeruiAg Station S'Wit:=-ya.rci (ft!,VNCSS"'. the Moenlto;:i Subsrac.o::.. or the Westwing S'Wit=::~...a.rci. Tuc:s:n ha.s owne:::::.=i:::er st or -s i" ?V'NCSS. the ~._.. .. ~Qenxo;:i S;':Qs:a.:i::-.. And :~e Wese-Ring S.r.rit=~~..a.:=. ~~. ,:8 ..., ='~~. ; .t... ~~ "' , '., .....- - ., .., t7 Appendix C - D3. D3. Z D4. ",-.~y :':'".~:~3.1 ...g:e~::-.e:-.: ~:: :~e ~J.::~es. :-:- :':0 . ':' .g:'e~::-.e:-.: ~S binding "J.?on :~e ?3.::ie S I..:.;:on :~e exec~:io:-. hereof. SEC-:-:ON D3 EXCH.o\NG E: Du.r:.:g the ter::-. hereo1. ~.i-R sha.U deliver to L\.:.cson its entitleme:lt :0 genera.tion at the Sa.n Jua.n Ciener3.ti:.g S~a.ti.c:u:~. Hour by hour. :'ucsoZ?-. w'iU deliver or w'iU a.r::1nge fo: :~e provision :0 M-R 0: a like acou::.: of C:1?a.e::.:-,. and the delivery of a like ..mot:::.: 0: as soc:i3.tec ene rgy a.: PVNCiSS. the MoenKopi S~cstation. or :~e WestWing Swite:~..,..a.rd. .... . There shoul:! be :::'0 i=bala.ne:e in energy deliveries.!A the eVent :::..u sue::' ; -!'! al:Lnces sh=u.1.d occur due to se:::.edweci or :.o:::.se::.eduled outages. :=:.e Opera.ti:1g Cc~-i::ee :epresenn.tives "...ill 3.:::t::.ge fo: sc:.eciules and celiver"f ::1tes to c::::ec: :~e imoa.lance. SEC-=:ON D4 5 CHEZJ U I.L'-l G Dur:.:g the pe rioa of the Agreement. M-A shall sc:h.ed\11e energy deliveries to Tucson by providi::.g Tue:son bY' the tWenty- !~::. (Z5~~) da.y ot ea.e:h coe.:::. a wrir:en e stir:a.~e of t::.e d aily e:nec We s 10: ::.e following r:-.on:~.1."'1 a.ddition. ~1.A will ;::ovice bY' Z ;:. c. ~.tour.:a.i: Sta.nda.rd 7!:ne eae:h day cu:ir.; the :e:::-. ~e:eoi an es:i::-'3.:e 01 the following day s r.our-oy-nou: Appendix C - 3 :)3. ~ DC;. 1 Dl O. 1 Dll. 1 SEC":":::~! DS ~ c-.-,., ~.- -- . -- '1-'.- .. -.:::..;,....., .~..:...;,. '-: . ~ u.. ':"':"... ':".. - ~ei:~er ?:lr:y shall '..olU::3.rily assign ::-.i.s .':"gre:ment ar a.ny pa.r: :~ereoi wi.::o.cu: the written consent of the ocher ?2Lrty. except i:-. =onnec:ion with. the sale or merger of a. substa.ntia.1 portion of its proper:ies. .SEC-:-:ON DC; NO :JE=:C.; 7ION OF FAC!:':':'~S ~c.~, c.::er:3.ki:.g by one ?~":',. to the other ~er a.ny prevision of :::.is Agreement shaU .::.ot consti:~:e t!:.e ciedica.tiaZ1 .... . of the sYStec:. or any per=-en cereof of either ?a.r:-r ta the publlc or to the ocer Par:;. a.nd i: is understaed a.nd a.greed t!:at a:y sue.:. u:cier:a.ki::.g by ei:::.er Pa.r:y sha..llcea.se u?on t.!:e ter=.'"'Ia :ian 01 :.=..s Agree::"'~=. SEC-::ON D10 ::~!P.PARTY R!CiE7S Not.~i::.g i::. t!:.is Agreement sha.ll be constrt:eci to eXtend a.ny benel1u to, or c:e&te a. ca.use oC actioZ1 by. any t==d party. SEC-:-:ON D11 G:C:~:--\L ?ROYISIONS 7he COm;:ensa.t:.o::.. :ates, charges. terms a.nd canditiaru as s'Peci:1eci herein sh.a..1l rema.in in eiIect Car t:.e term ai t!:.is Agreemen: a.nd sha.ll r.ot be subject to c:ha.nge through Ciling with, Appendix C - 5 DeS1 D13. 1 ?r'ovidec so Long a.s :~e c:a.?a.ciH:y 01 the t:a.nsmission facilities is not i~;::a.i:ec or :- ~cson s c:cnti:uu:y 01 service is nat jeopardi:eci thereby. S:E:C7:0N D13 TRANSMISSION LL"t:E: Tucson hereby C:Oc.sents to M-s future rignt to construe: a. tra.nsr-..i.uion line to connect witn the Sa.n Jua.n. Switchya.rc subject :0 the !oUowing conditiozu (a.):ha.t M-R or its aifilia.tes pay the entire coSt 01 sa.id construc:ion a.nd tklat c.o costs .A - be bor:e by Tucson: (0)that s~d i:te rc:cc.nection with the switc:,ard be made so a.. not to impair sy.tem c:a.pa.bility. jeopa.rdi:e the conti:w:y of service. or restrict ':"ucson I S a.bili =-r to tra.nsac:: with t:irc:! ;:a.r:ies at the Sa-c. Juan Switc:,ard: a.nd (c)that M-R o btaic. concurrence of PNM. IN WI7NESS 'WHE:E.E:OF. the Parties have caused t!:is Agreemeat to be executed as 01 Z9th Novemberday of . 1981. M-S-R PUBLIC ?OWE:R ACi~NCY By g/' rz;~ ..... ' Appendix C - 7 0(7) APPENDIX D r~'I'!:~:::;:U:c-.. :::: ftG ~';:"-=-.::':' be-cween :'~CSC:; ~=!'.!C ?OWE~ C::1PAl~Y anci M-S-?" PUBI.:= POWER AGI:N~l SEI'.VIC!: SCHEDUT-:E: RESERVE SHARING This Service Scheciule E is aqreeci upon as par': of the Inter- ccnnec':~=n Aqreemen': en~ereci i~~o between TUCSON t~c:~C POWER COMPANY ("Tucson ) and M-S-R PUBLIC POWER AGENCY ("M-S-R" This Service Scheciule E snail be deemed. ef:ec~ve when the purc."1ase of an undi"/ided 28.6\ ownership interest i~ San Juan Genera t~~q S ta tion Unit No. ( " Uni t No.) from PNM is completed by M-S-R.This Service S~"1edule shall be in effec,: thereafter for the life of Uni ~ No.4 or \.:..~ til terminated by ei t.~er P ar':j upon three (3) years advance wri':,:en notice. -=" .,-.. ':'his Su"lice Scheciule E sets fcr':.~ the ter::s and. candi- tions under which ~e par,:ies shall share the reserve capacity and ~"1e reserve liability associated wi~~ and occasioned by their respective ownershij;:1 interest in unit No.4 and in San Juan Genera tin; ta tion Unit No.1 and Unit No. ( " Uni: No.1" and Uni t No. ::" It is ccntamplated that M-S-~ will acquire an undivided 26.8\ ownership interest i~ Unit No. ~ on May 1. 1995.said 28. ownership interest i~ Unit tlo. 4 is est;r-a ted to be 138 !on" capaci ':7 and energy.When M-S-R acquires said ownership interest , " . ~~ Uni~ No. ~, the Par':ies hereby aqree ~~at M-S-R will as81qn tor~.~r-;~,r'~!'f:1 Appendix'D - ;:. '; Sta:~-up ener;:t obligations :0:' the M-S-R snare of Uni:. ~:Q. ~ will ~e f=~ished to PNM by M-S-R and s1;a.rt-up enerqy o~li;a1;ions :0: :.te T~cson share of Unit No.1 and Uni:. No.2 will be :~~shed to ~NM by Tucson. When Unit No.4 is dawn. Tucson will schedule s~rt-up ener~J to PNH for M-S-R.If Unit No.1 or Unit No.2 is op.ra~n;, M-S-R will schedule a like amount of energy from its capacity rights in said operating unit to Tucson.If beth Unit No.1 eel Unit No. 2 are not operating, Tucson will maintain an account of enerqy scheduled to PNH for M-S-R and M-S-R will return a like amoun:. of enerqy to Tucson within 60 days of the date that Unit No.1. Unit No.2 or Unit No.4 is returned to service. In t.~e event San Juan Unit-No. 1 or Unit No.2 should be subj ected to an extended outage other than a normal maintenance outage, Tucson will assign an equal amount of Reserve Sharuc; capacity to M-S-R from the other San Juan unit until the San Juan Unit experiencing ~~e extended outage is returned to service. In t.~e event San Juan Uni t No.4 is s ubj ec1;ed to extended outaqe other a normal maintenance ouaqe, M-S-R and T~cson will. four months after the start of the outaqe, sus- pend Reserve Sharing until San Juan Unit No.4 is retu..'"":1ed to service. Executed this a.3~d~Y of ~, 198~. TUCSON E:U:C":P.IC POWER COMPANY M-S-R PUBLIC po~'lEa AGENCY r-lC. //:v Appendix D - 3 . ,..- _... (' \ "" " OW E R E X C H A N G E E X A M P L E S EX A M P L E I b Ass u m p t I O n s . P a c l l i C o r p s c h e d u l e I r o m S a n J u a n = 1 2 . 00 0 M W h / m o n l h l o r 1 1 m o n l h s r c o n t r a c t y e a r . A d d l t 1 E n e r g y D e l i v e r y O p t i o n e t e c t e d b y R e d d i n g ( I 9 . 2 7 1 : I O p ti o n 2 . S h o r H a l 1 E n e r g y : R e d d i n g s c h e d u l e s 5 MW h a t S e a s o n a t E n e r g y l o r 5 0 h o u r s i n A u 9 01 2 0 0 0 I i i 92 2 4 1 XE A f U De e Ja n Fe b Ma r Ap r Ma y Ju n Ju t Au g Se p Qc l Na Y 2. Q J l J J mi l l ZIl . Q . Q 2.Q J l J J 2. Q J l J J 2. Q J l J J 2. Q J l J J 2.Q J l J J 2. Q J l J J 2.Q J l J J 2M I I 2M I I li t l a l PA C I F I C O R P . S a n . J u a n E n e r a v Am o u n l S c h e d u l e d . MV \ / h 12 , 00 0 12 . 00 0 t2 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 , 00 0 13 2 , 00 0 RE D D I N G . S e a s o n a l E n e r g y Ac c r u e d ( ~ d , C . " . , . o v e r l . MW h 12 . 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 , 00 0 10 , 00 0 13 0 , 00 0 Ma x H o u r l y R a t e 0 1 D e l i v e r y . M W M u Am o u n l S c h e d u l e d I S 9 , 2 & 9 . 22 3 1 M W h IU S I I li . ~ 1 1 ZL . 5 1 1 1 1 2. l . . l l i Hi . 2S 1 1 1. 6 . 25 0 12 0 . 00 0 To t a l A c c r u e d a n d R e m a i n i n g . M W h 12 , 00 0 00 0 36 . 00 0 48 , 00 0 60 . 00 0 55 . 75 0 51 . 50 0 36 , 00 0 20 . 50 0 16 . 25 0 00 0 00 0 Ca r r y f o r w a r d 1 0 n e x t y e a r I S 9 2 , 26 1 . M W h 10 . 00 0 10 , 00 0 BE D D I N G . A d d i t i o n a l E n e r g v Ac c r u e d W i n t e r E n e r g y I n c I , C . " Y , o v e r l . MW h 50 0 50 0 Ac c r u e d S h o r H a l l E n e r g y . MW h ZS O Ac c r u e d A d d i t i o n a l E n e r g y . U W h 75 0 50 0 25 0 Ma x H o u r f y R a l e 0 1 D e l i v e r y (1 1 0 2 1 . M W M i r Ma x M o n l h l y R a t e 0 1 D e l l w r y 1 1 1 0 . 21 . M W h l m o to , 30 0 10 . 30 0 to , 30 0 10 . 30 0 10 . 30 0 30 0 Am o u n l S c h e d u l e d . U W h l. 5 Q ZS I I 1:1 To l a l A c c r u e d a n d R e m a i n i n g . U W h 75 0 75 0 15 0 50 0 50 0 Ca r r y f o r w a r d 1 0 n e x t y e a r I S 8 , 61 . M W h 50 0 1. 5 0 0 t'J YE m Z De e Fe b Ju t Se p Oc l Na y Ja n Ma r Ap r Ma y Ju n Au g r- J 2M 1 2M 1 2M 1 2M 1 2M 1 2M 1 2M 1 2M 1 2O i l 1 2M 1 ZQ J l 1 ZI I I U J. g l i t l PA C I F I C O R P . S a n . J u a n E n e r a v Am o u n t S d l e 4 J I e d . MV \ / h 12 , 00 0 12 . 00 0 12 , 00 0 12 , 00 0 12 , 00 0 12 . 00 0 12 , 00 0 12 , 00 0 12 , 00 0 12 , 00 0 12 , 00 0 13 2 , 00 0 RE D D I N G . S e a s o n a l E n e r g y Ac c r u e d ( D e e 1 n c b I e , C a r r y - o v e r l . M W h 22 . 00 0 12 , 00 0 12 , 00 0 12 , 00 0 12 , 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 , 00 0 12 , 00 0 13 0 , 00 0 Ma x H o u r l y R a t e o f D e l i v e r y . M W M I r Am o u n l ~d . M V \ / h 1 D . . l : i i I 1L l : i O iU . Q . Q zu g l l J.. I . 1 . 5 . D l. D . . . l : i O 13 1 W 1 0 1 1 To l a l A c c r u e d I n d R e m a i n i n g . U W h 22 , 00 0 00 0 46 . 00 0 58 . 00 0 70 , 00 0 63 , 25 0 56 . 50 0 41 , 00 0 25 , 50 0 18 , 75 0 Ca r r y f o r w a r d 1 0 n e x t y e a r I S 9 . 2 . 61 . M W h BE D D I N G - A d d i U o n a i E n e r a v Ac c r u e d W I n t e r E n e r g y ( n c l . CI I f Y . - 1 . MW h 50 0 00 0 10 , 50 0 Ac c n t e d S h o r t . f l l En e r g y . MW h Ac c r u e d A d I I l l o n a l E n e r g y . U W h 50 0 00 0 10 . 50 0 MI x H o u r l y R l I . 0 1 D e l M r y ( 1 1 0 . 2) . M W M v MI x M a n t h l y R a l . o f De I w I I r y C I I 0 . 2 . . IM I I I - 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 Am D u n I . I M I 8 UJ U I I. Q Q Q 1.I L : i D G To t a ' A c c r u e d a n d R a m a / n l n g . M W h 50 0 00 0 Ca r r y f o r w a r d 1 0 n . x t r e a r ( I . . I) . M W h re . EX C H A N G E E ~~ I ~ EX A M P L E 2 b As s u m p l l o n s : . P a c l l i C o r p s c h e d u l e I r o m S a n J u a n = 1 5 . 00 0 M W h l m q n l h l o r 1 1 m o n l h s er c o n l r a c l y e a r . . A d d l 1 1 E n e r g y D e l i v e r y O p l i o n e l e c l e d b y R e d d i n g I S 9 2 , 2 7 ) : li o n 2 . S h o r t . Fa l l E n e r g y : R e d d i n g s c h e d u l e s 5 MW h 0 1 S e a s o n a l E n e r g y l o r 5 0 h o u r s I n A u g 01 2 0 0 0 I S 92 2 4 ) rE M l l De e Ja n Fe b Ma r Ap r Ma y Ju n Ju t Au g Se p Oc l No v 21 1 I l ! ! ZD 2 Q ZI l I l Q ZI l I l Q ZI l I l Q ZI l I l Q ZD 2 Q ZI l I l Q ZD 2 Q ZI l I l Q ll l l l ! ! za l l ! ! Ut i l i PA C I F I C O R P - S a n j u a n E n e r a v Am o u n l S c h e d u l e d . M W h 15 , 00 0 15 . 00 0 15 , 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 , 00 0 15 . 00 0 15 . 00 0 15 , 00 0 16 5 . 00 0 ED D I N G Se a s m a l Eo c U I I I Ac c r u e d ( n d . C8 f I y - - t . MW h 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 10 , 00 0 13 0 00 0 Ma x H o u r t y R a l e 0 1 D e H v e r y . Am o u n l S c h e d u l e d ( I 1 , 2 1 1 , 3) M W h 1L U Q u. . 5 . Q g Ro l l i JR o 2 ~ g 1 z O . OO g To l a l A c c N e d a n d R e m a i n i n g . MW h 12 . 00 0 00 0 36 . 00 0 48 , 00 0 60 . 00 0 55 . 75 0 50 0 36 . 00 0 20 . 50 0 16 . 25 0 10 . 00 0 10 , 00 0 Ca r r y l o r w a r d lo n e d y e a r (I 9 , 61 , MW h 10 . 00 0 BE U D J Ad d i l l o n a l ft w ~ AC C N e d W l n l e r E n e r A Y I i n c l . e a r l y . o v e r ) . M W h 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 3. 7 5 0 26 . 25 0 Ac c r u e d S h o r t - Fa n E n e r g y . M W h il l 15 0 Ac c r u e d A d d i l i o n a l E n e r g y . MW h 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 00 0 25 0 75 0 27 . 00 0 Ma x H o u r t y R a l e 0 1 D e l i v e r y ( l I D 2 ) 0 M W M u Ma x M o n l h l y R a l e 0 1 D e l i v e r y ( 1 1 0 , 2) . M W h / m o 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 , 30 0 Am o u n l S c h e d u l e d . M W h l. Z 5 0 l. l l O l. Z ~ l. Z . 5 0 10 . 31 l ! ! J9 . 30 0 't J To l a l A c c r u e d a n d R e m a i n i n g - MW h 14 . 25 0 70 0 70 0 25 0 25 0 25 0 25 0 25 0 50 0 75 0 00 0 12 , 00 0 14 , 25 0 ::I Ca r r y l o r w a r d 1 0 n e x l y e a r I I 9 . 2 , 6) . M W h 70 0 70 0 1" : 1 YE A 8 . . 2 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju l Au g Sa p Oc l No v ZI l ! I . J ZI l O J ZI l O J ZI l O J ZI l O J ZI l O . . 1 ZI l O J ZI l O J ZI l O J ZI l O J lJ l ! I . J 20 ! I . J Ig l i 1 1 PA C I F I C O R P - S a n J u a n E n e r a v Am o u n l S c h e d u l e d . M W h 15 . 00 0 15 , 00 0 15 . 00 0 15 . 00 0 15 , 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 16 5 , 00 0 RE D D I N G . S e a s o n a l E n e r a v Ac c N e d (O I l C I n c I u d 8 8 C I I ' I Y - C l v e r l . M W h 22 , 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 13 0 / " " " " Ma x H o u r l y R a l e o f D e l i v e r y . M W M v Am o u n l S c h e d u l e d . M W h 1I . l 5 J I 1I . l 5 J I 21 . l l i 1J . l 5 1 1 1J . l 5 g 13 g . aU O To l a l A C C N e d a n d R e m a i n i n g . M W h 22 . 00 0 00 0 46 . 00 0 58 . 00 0 70 . 00 0 63 . 25 0 56 , 50 0 41 . 00 0 25 . 50 0 18 . 75 0 Ca r r y f o r w a r d 1 0 n e x t y e a r ( 1 1 1 . 61 0 M W h fl E D D I N G Ad d i t i o n a l En I . a m l Ac c r u e d W i n t e r E n e r g y (I n c f . C l I ' l y o o v e r l 0 M W h 95 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 11 . 25 0 4\ . 4 5 0 Ac c r u e d S h o r t . Fa n E n e r I W . M W h Ac c r u e d A d d l l i o n a l E n e r g y . M W h 95 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 11 . 25 0 41 . 45 0 Ma x H o u r l y R a l e o f D e l i v e r y ( 1 1 0 2 1 . MW M I r Ma x M o n l 1 l y R a l e o r D e U v e r y ( 1 1 0 , 21 . M W h l m o 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 , 30 0 10 . 30 0 Am o u n l S c h e d u I 8 d . M W h Ln g LU l l LU l l LU l l 10 . 30 1 1 Zz . g g O To t a l A C C R J e d a n d Re m a i n i n g . M W h 95 0 25 0 25 0 25 0 25 0 50 0 75 0 00 0 11 . 25 0 13 . 50 0 75 0 14 . 45 0 45 0 Ca r r y r o r w a r d 1 0 n e x t y e a r f I 1 . 2 . 6) . M ' W h 14 . 45 0 45 0 r.s ( ' EX C H A N EX A H I " t . EX A M P L E 3 b As s u m p l l o n s : . P a c i l i C o r p s c h e d u l e I r o m S a n J u a n = v a r i o u s m o n l h l y a m o u n l s . I O p l i o n 2 I . A d d l n E n e r g y D e l i v e r y O p l i o n e l e c l e d b y R e d d i n g ( I 9 , 7) : . S h o r t . Fa l l E n e r g y : R e d d i n g a c c r u e s v a l i o u S a m o u n l s 01 S h o r t - Fa l l E n e r g y ( S 92 2 4 ) YE m . 1 De e Ja n Fc b Ma r Ap r Ma y Ju n Ju l Au g Se p Oc l No v 20 Q J J 2Q J J O 20 0 0 2O . O . Q 2O . O . Q 2O . O . Q 2O . O . Q 2O D t I 2J M l O 20 0 0 20 Q J J Jj ) l a l PA C I F I C O R P . S a n J u a n E n e r a v Am o u n l S c h e d u l e d . M W h 15 . 50 0 15 . 00 0 00 0 12 . 00 0 00 0 50 0 50 0 ' 1 5 . 60 0 16 . 00 0 12 . 00 0 90 0 13 0 . 00 0 RE D D I N G - S e a s o n a l E n e r a v Ac c r u e d ( I n d , C8 r I y - ) . MW h 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 00 0 50 0 50 0 12 . 00 0 12 . 00 0 12 . 00 0 90 0 11 3 90 0 Ma x H o u r l y R a l e 0 1 D e U v e r y . MW M v Am o u n l S c h e d u l e d ( f 8 . 2 , 2 & 9 , 2. 2 3 1 M W h Hi . 2 : i O l& . 2 : i J 1 1. 6 . 2 5 0 16 . 25 1 1 11 1 5 . 00 0 To l a l A c c r u e d a n d R e m a i n i n g . MW h 12 . 00 0 24 . 00 0 36 . 00 0 48 . 00 0 55 . 00 0 45 . 25 0 36 . 50 0 28 . 50 0 20 . 50 0 16 . 25 0 90 0 90 0 Ca r r y l o r w a r d 1 0 n e x t y e a r ( I 9 2 2 61 . M W h 90 0 90 0 BE D D I N G . Ad d i l i o n a l .f n e r l l r Ac c r u e d W l n l e , E n e r A Y l i n d , Ca r r y . o v e r ) , MW h 62 5 25 0 50 0 70 0 00 0 12 . 01 5 Ac c r u e d S h o r t . Fa n E n e r A V . M W h :i O O 3: i 1 l 55 0 L~ I l O Ac c r u e d A d d l l i o n a l E n e r g y . MW h 62 5 25 0 50 0 50 0 35 0 70 0 00 0 55 0 13 . 47 5 , M a x H o u r l y R a l e 0 1 D e l l y e r y 11 1 0 2 1 , MW M " Ma x M o n l h l y R a l e 0 1 D e l i v e r y 1 1 1 0 , 2) . M W h / m o 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 , 30 0 't J Am o u n l S c h e d u l e d . M W h 2. 6 2 5 2. Z 5 0 1. . ~ l. 1 . D I I 13 . HI : ! To l a l A c c r u e d a n d R e m a i n i n g . M W h 62 5 25 0 50 0 50 0 85 0 55 0 55 0 5& 0 10 0 Ca r r y l o r w a r d 1 0 n e x t y e a r I f 9 , 61 . M W h .. . . r: I Yf A R . 2 De e Ja n Fe b Ma r Ap r Ma y Ju n Ji l l Au g Se p Oc l Na Y ZQ g J ZQ g J ZQ g J ZQ g J ZQ g J ZQ g J ZQ g J 2n 1 U 2M ! Z.D I U ZO I U Io l a l 17 \ pA C I F I C O A P . S a n J u a n E n e r a v Am o u n l S c h e d u l e d . M W h 14 . 00 0 15 . 50 0 15 . 00 0 14 . 00 0 50 0 50 0 00 0 15 . 00 0 16 . 00 0 15 . 00 0 50 0 00 0 13 0 00 0 ~E D D I N G Se a s o n a l Eo I I s w Ac c r u e d ( D e e n : t u d e l C8 r I y - o v e r ) . M W h 20 . 90 0 12 . 00 0 12 . 00 0 12 . 00 0 50 0 50 0 00 0 12 . 00 0 12 . 00 0 12 . 00 0 50 0 00 0 11 8 . 40 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y . M W M I r Am o u n l S c h e d u l e d . M W h 1i . l l i 1i . l l i 1U Q O lU : i O t6 . 2 : i O J. U i . . - " To l a l A c c r u e d a n d R e m a i n i n g . MW h 20 . 90 0 32 . 90 0 44 , 90 0 56 . 90 0 63 . 40 0 53 . 65 0 45 . 40 0 32 . 40 0 18 . 00 0 13 . 75 0 00 0 00 0 Ca r r y l o r w a r d 1 0 n e x t y e a r I f 9 , &) . M W h 00 0 00 0 RE D D I N G Ad d i l l o n a l En m m ! Ac c r u e d W l n l e , E n e r g y I i n d . Ca r r y . o v e r l . M W h 1. 5 0 0 62 5 25 0 1. 5 0 0 25 0 00 0 25 0 15 . 37 5 Ac c r u e d S h o r t . Fa l E n e r g y . MW h :i O O 50 . . 0 20 0 LZ i l l ) Ac c r u e d A d d i t I O n a l E n e r g y . M W h 1. 5 0 0 62 5 25 0 50 0 50 0 50 0 25 0 00 0 25 0 20 0 16 . 57 5 Me x H o u r l y R I l l e 0 1 D e l i v e r y ( f 1 0 . 2) . M W M I r Ma . M o n l h l y R a l e 0 1 De l l Y 8 r y I f 1 0 . 2) . M W h f m o 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 Am o u n l S c h e d u I e c I . M W h 1. . U J I 2. i 2 5 us a ua o ZO O tu n TO l a l A c c r u e d a n d R e m a i n i n g . M W h 50 0 62 5 25 0 50 0 50 0 00 0 25 0 25 0 50 0 70 0 Ca r r y l o r w a r d 1 0 n e x t y e a ' C I 1 . 2 . 8) . M W h APPENDI:X F EXAMPLE CALCULATI:ON ESTABLI:SBI:NG ADJUSTMENTS FOR I:NTEREST Simple interest "Mid-year Convention H shall be' utilized in calculating the amount of the adjustments for interest. AssumDtions For ExamDle Calculations:(1) Total Annual Payment Difference for Contract Year December 1, 1996 through November 30, 1997 $12,000(2) Prime Ratell) (3) Time of Adjustment October 1, 1998 Ad'iustments For I:ntere.t 191: Interest Rate Dec 1996-Nov 1997 Dec 1997-Sep 1998 Prime Ra e.iJJ.E'actorI2) 0% multiplied by 9 . 0% multiplied by 1/2 10/12 50% 50% 12.00% 12.00% x $12,000 = $~40 Adjustment For Interest (1 )The prime rate shall be the time weighted average prime ratefor the period. For the example above it would be for the period January 1996 through September 1998. The prime rateshall be as established by l)Morgan Guaranty Trust Company New York, or 2) mutual agreement of the Parties. (2 )December 1996-November 1996 December 1997 -September 1998 mid-year convention 1/2 year 10 months Appendix F - 1 OW E R E X C H A N E E XA H P L E I EX A M P L E 3 8 "'s s u m p h o n s : . P a c l l i C o r p s c h e d u l e l r o m S a n J u a n = v a r i o u s m o n l h l y a m o u n l s , . A d d i l 1 E n e r g y D e l i v e r y O p l l o n e l e c l e d b y R e d d i n g ( I i , 7) : I O p l i o n I I . S h o r t - Fa l l E n e r g y : R e d d i n g a c c r u e s va r I O u s a m o u n l s 0 1 S h o r t - Fa l l E n e r g y ( S 9 . 24 ) , :t . E A B . . 1 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju l Au g Se p Oc l No v ZJ l D n ZO O i l ZJ l D n ZJ l D n ZJ l D n ZJ l D n ZJ l D n ZJ l D n ZJ l D n ZJ W I Z I l O . Q ZI l O . Q JQ 1 a J PA C I F I C O R P - S a n J u a n E n e r a v A~ n l S c h ~ d . 15 , 50 0 15 . 00 0 14 , 00 0 12 . 00 0 00 0 50 0 50 0 15 . 60 0 16 . 00 0 12 . 00 0 90 0 13 0 00 0 RE D D I N G Se a s o n a l EI w m t Ac c r u e d r i n d , C8 l l ' Y - ) - MW h 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 00 0 50 0 50 0 12 . 00 0 12 . 00 0 12 . 00 0 90 0 11 3 . 90 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y . M W M v Am o u n l S c h e d u l e d I I 9 , 2 & 9 2 . 3) M W h lL l l O 1U . . 5 . Q R. O i I i I R. O i I i I 1L Z ~ 1U . . 5 . Q 10 : i . OO O To l a l A c c r u e d a n d R e m a i n i n g . M W h 12 . 00 0 24 . 00 0 36 . 00 0 48 . 00 0 55 . 00 0 45 . 25 0 36 . 50 0 28 . 50 0 20 . 50 0 16 . 25 0 90 0 90 0 Ca r r y l o r w a r d 1 0 n e x t y e a r I I 9 2 . 26 ) . M W h 90 0 90 0 BE D D I N Ad d i t i o n a l Er u I ( g ! f Ac c r u e d W l n l e r E n e r g y I n d . Ca r r y . o v e , ) - M W h 50 0 00 0 00 0 60 0 00 0 Ac c r u e d S h o r t - Fa l l E n e r g y . :i J U I ;1 . 5 . 1 1 .I I .I I :i : i ! ! !- . . Ac c r u e d A d d i t i o n a l E n e r g y . 50 0 00 0 00 0 50 0 35 0 80 0 00 0 55 0 17 . 50 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y 11 1 0 2 ) . M W M I I Ma x M o n l h l y R a l e 0 1 D e l i v e r y 1 1 1 0 , 2) - M W h f m o 15 5 32 5 68 5 't I Am o u n l ~~ e d . Ll l 5 1. 3 2 . 5 61 1 5 16 . 16 : i To l a l A c c r u e d a n d R e m a i n i n g . M W h 50 0 50 0 50 0 34 5 52 0 87 0 47 0 47 0 47 0 02 0 33 5 33 5 Ca r r y f o r w a r d 1 0 n e x t y e a r ( I 1 1 . 2 , 6) . M W h 33 5 33 5 .. . tI J YE M l 2 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju I Au g Se p Oc l No v ZJ L I I j ZJ L I I j ZJ L I I j ZJ L I I j ZJ L I I j ZJ L I I j ZJ L I I j ZJ L I I j ZJ L I I j lD l U ZU l U ZU l U rQ l i l I PA C I F I C O R P . S a n . l I a n E n e r a v Am o u n l S c h e d u l e d . 14 , 00 0 15 . 50 0 15 . 00 0 14 . 00 0 50 0 50 0 00 0 15 . 00 0 16 . 00 0 15 . 00 0 50 0 00 0 13 0 . 00 0 RE D D I N G . S e a s o n a l E n e r a v Ac c r u e d ( D e e I n d u d e I C8 l l ' Y - o V l l r ) . M W h 20 . 90 0 12 . 00 0 12 . 00 0 12 . 00 0 50 0 50 0 00 0 12 , 00 0 12 . 00 0 12 , 00 0 50 0 00 0 11 8 . 40 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y . M W M v Am o u n l S c h e d u I e c I . lU : i O zu . o . a 2U J l . 1 ! 1i . Z 5 . 0 lt i . Z: i O 11 6 . 40 0 To l a l A c c r u e d e n d R e m a i n i n g . M W h 90 0 32 . 90 0 90 0 56 . 90 0 63 . 40 0 53 . 65 0 45 . 40 0 32 , 40 0 18 , 00 0 13 . 75 0 00 0 2. 1 ' Ca r r y f o r w a r d 1 0 n e x t y e a r ( I 8 . 2 , 6) . M W h 00 0 00 0 BE D D I N G . A d d i U o n a l E n e r a v Ac c r u e d W l n l e r E n e r g y I n d . Ca , r y - o v e r ) . M W h 33 5 50 0 00 0 00 0 00 1 ) 00 0 00 0 21 . 83 5 Ac c r u e d S h o r t . Fa l E n e r g y . 5.0 . . 0 50 i 1 ZO I l 1. Z D O Ac c r u e d A d d i l i o n a l E n e r g y . 33 5 50 0 00 0 00 0 50 0 50 0 00 0 00 0 00 0 20 0 23 . 03 5 Ma l H o u r l y R a l e o f D e l i v e r y 1 1 1 0 , 2) . M W M " Mi l M o n l h l y R a l e 0 1 De l i v e r y 1 1 1 0 . 2) . M W h f m o 48 0 91 5 10 . 07 0 Am o u n l S c : h e d u I e d . MW h UJ D 2. 1 1 . 5 Ul . I l l 0 ZJ . ~ I i : i To l a l A c c r u e d a n d R e m a i n i n g . M W h 33 5 13 5 13 5 35 5 44 0 94 0 44 0 44 0 44 0 I 1 . 44 0 11 . 64 0 57 0 57 0 Ca r r y l o r w a r d 1 0 n e x t y e a r 1 1 1 1 , 6) . M W h 57 0 1. 5 7 0 '- - ' tO W E R E X C H A N G E E X A M P L E S EX A M P L E 2 a As s u m p h o n s : . P a c i l i C o r p s c h e d u l e I r o m S a n J u a n = 1 5 . 00 0 M W h l ~ l h l o r 1 I m o n t h s r c o n l r a c l y e a r . A d d i l ' E n e r g y D e l Y e r y O p l l o n e l e c t e d b y R e d d i n g ( I 9 2 . 7): ll o n 1 . S h o r t . Fa l l E n e r g y : R e d d i n g s c h e d u l e s 5 MW h 0 1 S e a s o n a l E n e r p y l o r 5 0 h o u r s i n A u g 01 2 0 0 0 ( ~ 9 2 2 4 1 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju t Ao g Se p Dc I Na Y ZO O O Zo . o O ZD . Q . O ZD . Q . O ZD . Q . O ZO 0 . 0 z. o o . o ZD . Q . O ZD . Q . O ZD . Q . O ZO l l O ZO l l O Ig l i l l PA C I F l C O R P . S a n J u a n E n e r a v Am o u n t S c h e d u t e d - M W h t5 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 16 5 . 00 0 RE D D I N G . S e a s o n a l E n e r a v Ac c r u e d I n : I , CM Y - I . MW h 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 10 . 00 0 13 0 , 00 0 Ma x H o u r l y R a l e 0 1 D e n v e r y . MW M w Am o u n l S c h e d u l e d I f 1 , 2 & 9 , 31 M W h 1i . l l i 1i . l l i ZU O O u. s o . o lL f i Q 1t i . Z : i 1 l lz . o . l I l I O To l a l A c e r o e d a n d R e m a i n i n g . MW h 00 0 00 0 36 . 00 0 48 . 00 0 60 . 00 0 55 . 75 0 50 0 36 . 00 0 20 . 50 0 16 . 25 0 10 . 00 0 00 0 Ca r r y f o r w a r d t o n e x l y e a r ( f 9 2 , 61 . M W h 10 . 00 0 10 . 00 0 DD I N G Ad d i b o n a l .E n ~ Ac c r u e d W i n l e r E n e r ! l Y I i n c l . Ca r r y , o v e r l . M W h 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 Ac c r u e d S h o l t - Fa n E n e r g y . M W h ll J I Z. . Ac e r u e d A d d i l i o n a l E n e r g y . M W h 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 75 0 00 0 00 0 35 . 75 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y ( f i O 2 1 ' M W " " " Ma x M o n t h l y R a l e 0 1 D e l i v e r y 1 1 1 0 , 21 . M W h l m o 68 5 71 0 13 . 25 0 Am o u n l S c h e d u l e d . M W h LI i 1 5 1. 1 0 13 . Z5 0 Z~ . II I To l a l A c c r o e d a n d R e m a i n i n g . M W h 00 0 00 0 00 0 31 5 60 5 60 5 &0 5 12 . 60 5 16 . 35 5 19 . 35 5 19 . 35 5 I 1 . 1 0 5 I 1 . 1 0 5 :: t Ca r r y f o r w a r d 1 0 n e x l y e a r ( I 9 , 61 . M W h I I . 1 0 5 11 . 10 5 .. . tI J YE A f l 2 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju t Au g Se p Oc l Na y ZO I I I ZD . I ! J ZD . I ! J ZD . I ! J ZD . I ! J 2D . I ! . 1 ZD . I ! J ZD . I ! J ZD . I ! J ZD . I ! J ZJ l I l l ZI ! . . I I . 1 Io r a l PA C I F I C O R P - S a n J u a n E n e r ; v Am o u n l S c h e d u l e d . M W h 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 16 5 . 00 0 RE D D I N G . S e a s o n a l E n e r v v Ac c r u e d ( D e e n c : b I I l C 8 R Y ~ V 8 r ) . UW h 22 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 13 0 . 00 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y . U W M w Am o u n l S c h e d u l e d . M W h .u . . . r n I .u . . . r n I 2L l l i 2L l l i 1L r n I 11 . 1 5 I I 13 1 1 . 0 0 0 To l a l A c c r u e d a n d R e m a i n i n g . MW h 22 . 00 0 34 . 00 0 46 . 00 0 58 . 00 0 70 , 00 0 63 , 25 0 56 . 50 0 41 . 00 0 25 . 50 0 18 , 75 0 Ca r r y f o r w a r d t o n e x l y e a r ( I 1 . 2 . 8) . M W h RE D D I N G . A d d i l i o n a l E n e r v v Ac c r u e d W i n t e r E n e r g y ( I n d . C. . - r y - o v e r ) . M W h 10 5 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 15 . 00 0 56 . 10 5 Ac c r u a d S h o l t . Fa . E n e r g y . UW h AC c r u e d A d d I I I o n a I E n e r g y . M W h 10 5 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 15 . 00 0 5& . 10 5 Ma x H o u r l y R a l e o f D e l i v e r y ( 1 1 0 , 21 . U W M v Ma . M o n t h l y R a t a 0 1 De l I v e r y ( 1 1 0 . 21 - M W h l m o 13 , 25 0 48 0 13 . 25 0 Am o u n t . M W h UI Q ~I I :u . s I I I I To t 8 1 A c c r u 8 d a n d R a m a I r * I g . M W h 10 5 17 . 10 5 20 . 10 5 85 5 37 5 37 5 10 . 37 5 13 . 37 5 16 . 37 5 18 . 37 5 34 , 37 5 21 . 12 5 2 I . 12 5 Ca r r y f o r w a r d 1 0 n e x t y e a r ( I 1 . 2 , 8) . M W h 21 . 12 5 21 . 12 5 \. . . / PO W E R E X C H A H G E E X A M P L E S EX A M P L E I e As s u m p l i o n s . . P a c i l i C o r p s c h e d u l e I r o m S a n J u a n = 1 2 . 00 0 M W h l m o n l h l o r 1 1 m o n l h s er c o n l r a c l y e a r , . A d d i l 1 E n e r g y D e l i v e r y O p I I O n e l e c t e d b y R e d d i n g ( t 9 2 . 7) : ll o n 1 . S h o r t - Fa l l E n e r g y : R e d d i n g s c h e d u l e s 5 U W h 01 S e a s o n a l E n e r g y l o r 5 0 h o u r s I n A u g 0 1 2 0 0 0 I t 92 2 4 ) :t f H U De e Ja n Fe b Ma r Ap r Ma y Ju n Ju l Au g Se p Oc l Na Y Z Q J U I ZO O O ZO l l O ZO l l O ZI l J 1 Q ZI l O O ZI l J 1 Q ZI l J 1 Q ZI l J 1 Q zo a o zo a o ZO l l O Ig l i J l PA C I F I C O R P Sa n . 1 J a n Am o u n l S c h e d u l e d . M I M I 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 13 2 00 0 BE D D I N G . S e a s o n a l En e l Q V Ac c r u e d ( i n c l . C. r r y - ) . U W h 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 10 . 00 0 13 0 , 00 0 Ma l l H o u r 1 y R a l e 0 1 D e l i v e r y . M W M v Am o u n l S c h e d u l e d I I 9 , 2 & 9 , 3) M W h 1& . 2 5 0 1U . S 0 ZL S O O ZL 5 1 l O 16 . . 2 5 0 I. 6 . Z S 0 12 0 . 00 0 To l a l A c c r u e d a n d R e m a i n i n g . M W h 12 . 00 0 00 0 36 . 00 0 48 , 00 0 60 . 00 0 55 , 75 0 51 . 5 0 0 36 . 00 0 20 . 50 0 16 , 25 0 10 , 00 0 10 , 00 0 Ca r r y 1 0 I W a r d 1 0 n e l d y e a r ( I 9 . 6) . M W h 00 0 10 , 00 0 BE U D I Ad d i l l o n a l fn l l Q l / Ac c r u e d W i n l e r E n e r l W ( i n c l . Ca r r y _ , ) . MW h 00 0 00 0 Ac c r u e d S h o r t . Fa l l E n e r g y . MW h il l 1. 5 0 Ac c r u e d A d d l l i o n a l E n e r g y . U W h 75 0 00 0 75 0 Ma l l H o u r l y R a l e 0 1 D e l i v e r y ( 1 ' 0 2 ) . M W h I h r )0 M i l l M o n l h l y R a l e 0 1 De l i v e r y 1 1 ' 0 , 2) . M W h / m o 32 5 :g A m o u n l S c h e d u l e d . MW I I l. 5 . o To l a l A c c r u e d a n d R e m a i n i n g . MW h 75 0 75 0 75 0 00 0 00 0 C1 o C a r r y 1 0 I W a r d 1 0 n e l d y e a r I I 9 . 6) . M W h 00 0 00 0 I'l l tI J De e Ja n Fe b Ma r Ap r Ma y Ju n Ju I Au g Se p De l No v no . ! ZQ . Q J ZQ . Q J ZQ . Q J ZQ . Q J Zn t ZQ . Q J ZQ . Q J Wt l ZQ . Q J ZQ . Q J ZO i i l li I l i l l .. . . P A C I F I C O F I P . S a n . 1 J a n En e l V Y Am o u n l S c h e d u l e d . M I M I 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 , 00 0 13 2 , 00 0 RE D D I N G . S e a s o n a l E n e r g v (/I Ac c r u e d ( O K n c : b I I I I Ce n y - o w e r ) . M W h 22 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 13 0 . 00 0 Ma . H o u r l y R a l e o f D e l i v e r y . M W h / h r Am o u n l S c h e d u l e d . M W I I 1L l ~ 1I . l l i 1I . . l l Q 1L Z 5 0 13 0 . 0 0 0 To l a l A c c r u e d e n d R e m a i n i n g . M W h 22 . 00 0 00 0 46 . 00 0 58 . 00 0 70 . 00 0 63 . 25 0 56 , 50 0 41 . 00 0 25 , 50 0 18 . 75 0 Ca r r y 1 0 I W a r d 1 0 n e l d y e e , I I 8 , 8) . M W h RE D D I N G . A d d i U o n a l En e I Q V Ac c r u e d W l n l e , E n e r g y (I n c l . C8 r r y - ) . M W h 00 0 12 . 00 0 00 0 Ac c r u e d S h o r t . Fa a E n e r g y . M W h Ac a v e d A d d I I I o R I I E n e r g y . MW h 00 0 12 . 00 0 14 . 00 0 Ma . H o u r l y R e l e 0 1 D e l i v e r y (1 1 0 . 2 1 . M W M v Me . M o n I h I y R e i . 0 1 D 8 h 8 r y (1 1 0 . 2 ) . M W I I I m o 59 0 32 5 10 . 33 5 Am o u n I S c : I M I I e d . M W I 1 tt . 3 . 3 5 1. 2 . J 3 5 To I I I A c c I U e d e n d R e m e ! n l n g . MW I 1 00 0 00 0 00 0 41 0 12 . 00 0 66 5 66 5 Ca r r y l o r w e r d 1 0 n e l d y e a ' ( I 1 , 2. 2 , 8) . M W h 66 5 66 5 \w i \. . , ) ----- --- ----....... t"'-:""'.;:a=~ ~nI::-na.~.: c: ~-5-F.capa.c:'-::t =~;htsi~ t:::.:.~ ~:o. and.::ZQ: wi~: i=. ~~-: aSS~;:1 -0 M-S-R ==: ::eserve P~-;oses an equal a:o~-: :: ~~cson I s capac~ -:7 =i;h~s i=. Unit No. : and U~i ~ ~o. :. -. :: is =ec:;~=ed '::~~ ~s Serv:.ce Schedule ~ is antered ~':= === the pU--;ose of ::ed~=:.~; ~~e reserve requirements of M-S-R and :~cson only and :..~ is understood tbat no ownership :::.qhts are i: any way to be affected :1 t:is Ser:ice Schedule It is understood ~~at M-S-?. will count as capacity one-hal= of its genera:ion entitlement in Unit No. 4 and ODe quarter in each 0: Uni~ No. : and Unit No. ~. and will scnedule =ro: these uni~ based on ~~eir availability.For purposes of enerq:( a.ccou~C;, M-S-?. hourly ener;y...entitlementS shall ba deter- mined by multiplying ~~e M-S-?. par:i:ipation percentage expressed as a deci~l quan:i~y by Uni~ No.4 hourly capability less the S-S-R hourly cur-.:u.lmen:of Unit No.1 and Unit No.2 less the M-S-R hourly cu=:ail=1en: of Unit No.Energy schedules wUl be adj usted to reduce ~ala.nces in the course of the year basad on tbe M-S-?, ener;y enc.tlementz.Adj us:=entS in the deliveries of ener;-,; to M-S-?. d~:..~; the =irzt two =n~ of the succeeding calenda: year will :e made based upon ~~e year end equali:aticn. ':his two-mcn~~ period may be extended by mutual a;ree- me.nt 0: the Opera:i:ns Co!!'!"!!l t~ee i: winter or spr:.:.q maintenance is s c:heduled on Un:. t No. : . Uni t No.2 or Uni t No.4 and the resulti::.g enerqy sh.i=~ is i:1 a balanc:.nq ciirection. 1:.No time li:it wi~1 be placed on ~~e shar:.nq of reserves in Uni ~ ~lo. :. U~i ~ :~o. : 0:: Uni ~ No. .;.However. enerqy i:bal- ances resul~~; ==:= ~~e sha:::.n; 0: =eserves will ~e l i~i ~ed to ~~e ener~. eq~~al~~-: of 60 days I opera~.:.:::. a~ l:O percent capa- ~i~v :ac~=~ o~era~:::. c= one-hal: := ~~e M-S-R en~.:.~eman~ in Appendix D - 2 '!"UC.sCN E!..~=:-~'..IC ?OWE:?. CCMPANY --0 ..,. - Appendix C - 8 D(S) ~ll. : ::n 2. : or a??i.ic~::'O:l :::, :~e :ecieral 2~ergy ?egui-uory C.;)::-.:nission ?ursuant to t~e ?:o...'isi,:::ls 0: Section 2.05 ot the Federa.l rower Ac:: absent the rn.u:~3ol agreement 01 the ?a.rties hereto.Neither Pa.r:y sha.ll request or i=.itia.te. directly or indirectly, a.C:UOft by said Ccm.cission for any cha.nge herein pursuant to Section ZO6(a) of said Ac:t. It i.1 w::I.cer Stood--a.nd a.greed th3ot this A greement is preciic:a.ted I.1pon the a.1Surn.;::lon th~t M-a.c:tua.Uy exercises i:5 Option to ac:~ulre an 1J..~divi~ed 2.3.8 perc:ent ownership in the S6n J~&A and relateci prope r:, i::.te re ses.La. ~he eVent that M'i\. doe. not exerc:i.1e its said Option a.nd does no: ac:~uire ownersiU.p in s&i.d San J~3on 4, then::is Agreeeen: saul be AWl a.nd void a=d of no effect. SZC-::~N D1Z USE c~ s...:"'N ;:;AN SVII-::::::AP. 7~c:son agrees tha.: ?OWer cie1lvered by M-R !rom its interest i:1 San Jua.n 4 to the San Jl.13on Switc::yard will be made ava.ilable l.1?on :equest 01 M-R to M-R or to third p3ordes a.: t..~e S3on Jl.13on S-.vitc:.ya.rc. I.1p to 144 megawa.:tS 01 ca.pa.c:i:v. at times wnen =e power exc::ange described herein is no: beiA! made a.t PVNCiSS. the Moenkopi Subs::a.:ion. or the Wescwing Swi:c:hyard. it being I.1ncerscood t::a.: suc:h 3ovailability will be Appendix C - 6 0(6) D5. D6. --- :)7. 1 :wenty-fol.l: \2..z./ ~Ol.l: schedule. .., SEC7:0N D ?O~TiS1 OF DEL:V~?. The roi:.:( s) 01 Delive ry for t:a.nsac:io~u hereunder shall be: (a):ror:1 M-R to 'I"~cson at the San J'~ Genera::.:g Sta.tion 345 kV Switc:yard. (b)Free 7~c",on :0 M-OLt PV'NCi~. the Moen~pi SUQsta.ticn. or the We 5tW'U1g Swi:c:.,ard. ..,. - . (c)Other ?oi=.:: of delivery as the Opera:i::.g r-.-"::ee repre sen:a.tives c:.a.y c:.=ually agree upon. SEC7::)N ~o LOSSES There are no lo", se s as socia:ed with the capacity' and energy deliveries cade to 'I"uc:on at Sa.n .I~&n and to M- at PVNCi~S. ::e MoerUto~i Substa:ioc. or the WestWing Switch. yard. SEC7:0N D7 CHARCES There sha.ll be co cha.:ges a.ssociated with the delivery of ca~aci:~1 .u~d energy a.ssocia.ted with t:-.is Agreement. Appendix C - 4 - . .. :)1. : ~l. ~z. : -----......, -,':::':'- - -.... :-I.\C~C:l ~= ~.~ - a oe5i:e to exc::.:u~ge M-s snare of c:apaci:~.. and assoc:iated energy !:o::-. :he net power p:oduc:ioz::L of San Jl.\an 4 lor a like a.moun: oi capacity and energy at PVNCS$. t..~e Moenkopi Sl.\bstation. or ::.e We stwing Switc::.- ya.rd. The .?a.r::.es rec:ogni:e that !:om ti=e to ti=e t::.ere may be scheciwec or ::.onscheciuled ou:age...s a.i!ec::i:.g the au:;:\:.: 01 Sa-A .Zua.:1 t1:i: 4.Eac::. ?a.r:; agrees to use its best efforts to nClt:L.~ t~ ccer ?uo':"f ~f~=ie:1u"f i::. advance cl sc~ciw.eci OUt.:Lges a.nd := C:=::ec:: aU ::'o%Uc~duled ou:a.ge s a.s soon as prac:::i::l.cle so as := ena.ole Ue eX:::~ge 0: ca.pa.ci:-r 3.:1C energ., t= :3.xe ;:iace ceC'\Veen ~e Parties as provi.ceci herein. SEC-:-:ON DZ 1"~?. The exc::.:t..::.;e :::.acie 1J.::.der :.:.is Agreement sha.ll be tor 30-yea.r ?ericd !ag 'i...-; Ma.y 1 . 1995. a.nd cay be extended ':"ppendix C - ....,., , ~he =eso~~ces placed i~to the Resource Pool may consis~ c: any c~~bination of resources PacifiCorp owns or may acqui~e. includi~g. but not l~mited to, thermal generation it owns or leases and firm power purchases under contracts with a term of three years or more; Drovided , that resources placed in the Resource Pool shall only be resources that (1) PacifiCorp acquires through prudent utility management practices and (2) have been declared to be in commercial operation prior to January 1 of the calendar year in which such resources are included in the Resource Pool; provided further. that no resources that utilize fissionable energy sources shall be included in the Resource Pool. Appendix B - 2 HUNTER #2 AND #3. M:INE :INVESTMENT FORMULAS FOR CALCt1LAT:INGIN:IT:IAL LEVELIZED F:IXED CHARGE RATE (Con I ( .. 6 )INCOME TAX INCOME TAX ( '*7)ANNUAL COST ANNUAL COST (Total Return + Book Depreciation + DeferredTax - Tax Depreciation) x (Tax rate/ (l-Taxrate) ($5,235+ $7,143 + $2,631 - $14,290) x3681/ (1-3681) = $419 Book Depreciation + Total Return + Interest + Deferred Tax + Income Tax $7, 143 + $5,235 + $4,028 + $2,631 + $419 =$19,456 ('* 8) TAX DEPRECIATION = (Modified ACRS) x Original InvestmentTAX DEPRECIATION = 14.29% x 1.00 x $100,000 = $14,290 9) ITC = Not Applicable ( '* 10 ) PRESENT WORTH ANNUAL COST = Annual COg t x 1/ (1 + i ) nPRESENT WORTH ANNUAL COST = $19,456x 1/(1 + .0974)1 =$17, 729 where i = weighted cost of capital and n = first year. ('* 11) INI7IAL LEVELIZED FIXED CHARGE RATE = (CRF x TotalPresent Worth Annual Cost) /Total Original Book Cost INI7!AL LEVELIZED FIXED CHARGE RATE = ( 0 . 13382 x$102.357)/$100.000 13698 13.698 Appendix A - 21 HUNTER #2 AND #3 M:INE INVESTMENT CALCULATION OF ADJUSTED IN:I'I':IAL FIXED CHARGE RATE (Based on $lGO. 000 of Capital Expenditure) CAPITAL STRUCTURE: ComDonent Structure DebtPreferred Cormnon 50% 10% ' 40% 47% 24% 11.70% Weighted Cost of Capital 74% INPUT DATA: INVESTMENT TAX CREDIT: SALVAGE VALUE: BOOK LIFE (Straight Line) TAX LIFE (MACRS ) TAX RATE TAX BASIS PW RATE Not 37.77% 100.00% 74% Applicable yearsyears(includes state Corp. tax) of Book CALCULATED DATA: l...J CAPITAL RECOVERY FAC~OR = 0.13382 (1 * ) INITIAL LEVELIZED FIXED CHARGE PATE = 0.13698 = 13.698% (*11) ADJUSTED INITIAL L~LIZED F:ZED CHARGE RATE* = 13.698% less book depreciation. where book depreciation = 1/14 years = 0.07143 =143% = 13.698% - 7.143% = 6.555% Book depreciation is reflected in fuel cost. Appendix A - 19 HUNTER #2 PROJECT ALLOCATEDMINING EXPENSE CALCULATI:ON (Based on 1990 Actual Costs) Ini tial ~evelized ~~nual Fixed Charae Hunter #2 Pro~ec~ Hunter #2 Mining Investment-$26,195,889 Adjusted Initial Levelized Annual Fixed Rate 551% Initial Levelized Annual Fixed Charge $1,716,093 Subsequent Investment Subsequent Levelized Annual Fixed Rate Subsequent Levelized Annual Fixed Charge Ad 'lalorem Tax Taxes, assessments and in lieu of taxes Administration & General Expenses: 1990 Total PacifiCorp A & G Expense = $145,713,190 1990 Total PacifiCorp 21ectric Plant In Service = 57,884,778,137A & G Expense as a percent of Investment = 1.85% Hunter #2 A & G Expense = 5484.108 Total $2,200,201 - See attached sheet A-16 for details. Appendix A - 1 ANNUAL VAR:IABLE COST CALCULAT:ION Based on 19~0 FERC Form 1 P~oi ec: Annual Load Factors :990 Colstrip L. F.= (951,695 MWh/8760 hrs) 1140 MW = 0.78 = 78% 1990 Jim Bridger L. F. = (9,727 673 MWh/8760 hrs)/1333 MW = 0.83 = 83% 1990 Hunter #2 L. F. = (1,772,948 MWh/8760 hrs) 1235 MW = 0.86 =86% 1990 Hunter #3 L. F. = (3,348.751 MWh/8760 hrs) 1400 MW = 0.96 =96% Weicrhted Variable Cost $/MWh = ( (70 MW x 78% x 12.98) + (95 MW x 83% x 14.79) + (235 MWx 86% x 12.80) + (400 MW x 96% x 11.70)) ((70 MW x78%) + (95 MW x 83%) + (235 MW x 86%) + (400 MW x 96%)) $/MWh = 12. Adjusted for Losses:IMWh = 12.45/0. Annual Variable Cost:513.10/Mtolh Appendix A - 15 Hunter Proj eet Annual Variable Cost (Based o~ 1990 FERC Form Production Sxcenses Operation, Supervision and Engineering Fuel Steam Expenses Electric Expense Misc. Steam Power Expenses Rents Maintenance, Supervision and Engineering Maintenance of Structures Maintenance of Boiler Plant Maintenance of Electric Plant Maintenance of Misc. Steam Plant Sub-Total Allocated Mining Expenses In Lieu of Payments Total Variable Costs Hunter ;2 proj ect Annual Energy Production (~1h) Hunter #2 proj ect Annual Variable Cost * See Attached sheet A-17 for details Appendix A - 13 359,749 14,892,163 255,642 710,564 740,621 874 542,858 367,544 488,547 149,289 (21,706) ---------- $20,486,145 $2,200,201 $22,686,346 772,948 $12.IMWh ------------------ Colstrip Project Annual Variable Cost (Based o~ 1990 FERC Form Colst~~D P~o~ec~ Annual Energy Production (MWh) Produc~~on Excenses Operation, Supervision and Engineering Fuel Steam Expenses Electric Expenses Misc. Steam Power Expenses Eents Maintenance. Supervision and Engineering Maintenance of Structures Maintenance of Boiler Plant Maintenance of Electric Plant Maintenance of Misc. Steam Plant Sub-Total In Lieu of Payments. Total Variable Costs Colstrip Project Colstrip proj ect Annual Variable Cost * Montana Electrical Energy License Tax Appendix A - 11 951,695 175,543 481,054 676,840 310,816 032,897 (97,341) 232,610 168,140 462,168 483,955 228,956 --------- $12.155,638 197,102 $12,352,740 $12.98 /MWh filing with the FERC :o~ a c~ange of rates to ~eflect any change :~ the rate of ROE as authorized by the FERC. A4.3 Book DeDreciation Book depreciation charges shall be at a straight-line rate based on a fourteen (14) year life in calculating the initial levelized annual fixed charge rates.Book depreciation charges for subsequent levelized annual fixed charge rates shall be based on the estimated remaining service life of the Project including the effects on such life due to the subsequent investment.Because book depreciation is reflected the Hunter #2 and #3 fuel cost, an adjustment is made to the initial levelized annual fixed charge rate for the Hunter #2 and #3 project mining investment, pursuant to Subsections A2. 3.1 and '\2. A4.Income Tax Reauirements Income Tax Requirements applicable in calcu~ating both initial and subsequent levelized annual fixed charge rates shall be based on the following items: provided, subsequent changes in tax laws shall be incorporated in computing levelized annual fixed charge rates for periods following such tax law chan~e: A4 .4 . 1 The federal corporate ~ncome tax rate, 46% up through 1986, 40% in 1987 and 34% for the years 1998 through 1992 and 35% in 1993 and thereafter. A4 .4 .A state corporate income tax rate equal to the estimated composite weighted average of PacifiCorp I s (3) three-factor formula for unitary allocation of state taxable income based upon payroll, p~operty, and revenue in each state Appendix A - 9 ....) :ixed c~arge rates and is as :ollows: Long - Term Debt 48% Preferred Stock Common Stock Equi Total 100% orovided , that if any part of PacifiCorp I s portion of the capital additions. replacements, or betterments which occasioned a subsequent levelized annual fixed charge cost is financed by long-term debt, the interest of which is exempt from federal income taxes, the long-term debt portion of the above capital structure shall be apportioned between the long-term debt and the tax exempt long-term debt accordingly.In no case shall the long-term debt portion exceed forty-eight (48%) of total capi talization. A4 .2 Cost of CaDi tal A4 . 2 . 1. 1 Lona-Term Debt Bond interest applicable in the calculation of each initial levelized annual fixed charge rate will be eight and forty-seven hundredths percent (8~ 47%) .Bond interest applicable in the calculation of each subsequent levelized annual fixed charge rate for future capital additions, replacements, or betterments shall be the effective cost rate to PacifiCorp of the most recent issue of long-term bonds, excluding special-purpose issues not related to the Hunter #2 and Hunter #3 Project Mining Invesament, in the twelve (12)-month period prior to the date of the completion of construction of the capital additions, replacements or betterments for which the subsequent Appendix A - 7 if any), and betterments of :~e Hunter #3 proj ect allocated mining investment, completed d~=~~g :he calendar year immediately preceding establishment of such subsequent levelized annual fixed charge.Such dollar investment, to be determined from data contain in PacifiCorp' s FERC Form 1 or its successor thereto, shall not include any dollar amounts incurred by PacifiCorp prior to January 1, 1991. A2.All ad valorem taxes imposed upon the Hunter Project mining investment. A2.Administrative and General Expense shall be an amount equal to the product of 1) the quotient of total PacifiCorp administrative and general expenses to total PacifiCorp electric plant in service: and 2) the total Hunter #3 Project mining inves tmen t Section A3:Alloca of Mi nina rn tmen ter 2 and Hunter Pro; ects Hunter #2 mining initial investment and Hunter #3 mining initial investment shall be determined by (a) multiplying the dollar amount as set forth in Section A3.1 by (b) the ratio of PacifiCorp's share of the associated Proj ect I capability (235 MW for Hunter #2 Project and 400 MW for Hunter #3 proj ect divided by the total capability of all Projects served by the mines (presently 1995 MW) Hunter #2 mining subsequent investment and Hunter #3 mining subsequent investment shall be determined by (8) multiplying the dollar amounts as set forth in Section A3. 2 by (b) Appendix A - 5 dete~ined pursua4~ to Section A3, as of December 31, ~990.=or purposes c: this sect~on, ?ac~: ~Corp' s total investment in Hunter #2 pro~ec~ ~ining :s S26,195.889.Such total investment shal: remain constant t~rough the book life (14 years) and shall be SO afterwards.Such adjusted initial levelized annual fixed charge rate shall be determined by subtracting book depreciation (1/book life) from PacifiCorp I s initial levelized annual fixed c~arge rate for the Hunter #2 proj ect mining investment determined annually in accordance wi th Section A4, below.Such book depreciation reflected in Hunter #2 fuel cost. A2.The sum of all subsequent annual levelized fixed charges, each of which shall be determined by multiplying (a) Paci:iCorp I s subsequent levelized annual fixed charge rate for each year, for the Hunter #2 Project mining investment, calculated in accordance with Section A4, below, by (b) the dollar investment in capital additions, replacements (less credit for net salvage and insurance proceeds, if any), and betterments of the Hunter =2 Project allocated mining investment, completed during the calendar year immediately preceding establishment of such subsequent levelized annual fixed charge.Such dollar investment, to be determined f~om data contain in PacifiCorp' s FERC Form 1 or its successor thereto, shall not include any dollar amounts incurred by PacifiCorp prior to January 1, 1991. A2.All ad valorem taxes imposed upon the Hunter #2 Project ~ining investment. A2.Administrative and General Expense shall be an Appendix A - APPENDIX A ANNUAL VARIABLE COST This Appendix sets forth the elements and tecr~iques to calculate the Annual Variable Cost. ct ion l :Determination of Annual Variable Cost The Annual Variable Cost shall be the $ /MWh result of the following:(1) the product of 70 MW multiplied by the Colstrip annual load factor multiplied by the Colstrip proj ect ~nual Variable Cost plus the product of 95 MW multiplied by the Jim Bridger annual load factor multiplied by the Jim Bridger Project Annual Variable Cost plus the product of 235 MW multiplied by the Hunter #2 annual load factor multiplied by the Hunter #2 Project Annual Variable Cost plus the product of 400 MW multiplied by the Hunter #3 annual load factor multiplied by the Hunter #3 Project Annual Variable Cost. (2) dividing the above sum by the total of 70 MW multiplied by the Colstrip annual load factor plus 95 MW multiplied by the ~im Bridger annual load factor plus 235 MW multiplied by the Hunter #2 annual load factor plus 400 MW multiplied by the Hunter #3 annual load factor, and (3) dividing the above ratio by 0.95 which represents the adjustment factor for transmission losses. Appendix A - 1 (a)To any person or encicy inco which or wich which the parcy making che assignmenc is merged or consolidated or to which che parcy cransfers subscancially all of its assets; (b)To any person or enticy wholly owning, wholly owned by, or wholly owned in common with the parcy making the assignment; ( c)The Redding Joinc Powers Financing Authority. Noching concained in this Seccion shall be construed to prevent PacifiCorp from making a collateral assignment of the revenues due under the terms of this Agreemenc.No assignment, merger or consolidation shall relieve any Party of any obligation under chis Agreement.Subj ect to the foregoing restrictions in this Section 21, this Agreement shall be binding upon, inure to the benefit of, and be enforceable by the Parties and their respective successors and assigns. Page 34 - LONG- TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING preserve the original intent contemplated by the Parties. the event the Parties are unable to renegotiate the terms and condi tions of this Agreement, this Agreement shall terminate within 60 days of receiving notification from FERC, any agency, or any court of competent jurisdiction requiring material modifications to this Agreement. 17.Waiver Any waiver by a Party to this Agreement of its rights with respect to a default hereunder, or with respect to any other matter arising in connection herewith, shall not be deemed to be a waiver with respect to any subsequent default or matter. No delay,short of the statutory period of limitations, asserting or enforcing any right hereunder shall be deemed waiver of such right. 18.Indemnification Neither Party (First Party), shall be liable whether in warranty, tort, or strict liability, to the other Party (Second Party) for any injury or death to any person, or for any loss or damage to any property, caused by or arising out of any electric disturbance on the First Party's electric system, whether or not such electric disturbance resulted from the First Party's negligent act or omission.Each Second Party releases the First Party from, and shall indemnify and hold Page 32 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING any such audit discloses that an overpayment or an underpayment has been made, the amount of such overpayment or underpayment shall promptly be paid to the Party to whom it is owed by the other Party plus interest at the prime rate as defined pursuant to Appendix 13.PacifiCorc I s Audit Riqhts PacifiCorp, at its expense, shall have the right to audit and examine any document in Redding I s possession related to the condition or operating performance of San Juan.Any such audit shall be undertaken by PacifiCorp or its representatives at reasonable times and with reasonable prior notice. 14.Notices All written notices, demands or requests required by the Agreement or the provisions hereunder, including billing invoices, shall be considered given when delivered in person, or prepaid telegram, or sent by first class mail, postage prepaid deposited in the u. S. Mail, directed as follows: Page 29 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING interest calculated at the prime rate as defined pursuant to Appendix F. 11.Billi~o and PaYment Schedules PacifiCorp shall bill Redding each month by certified mail for Firm Capacity and Firm Energy provided during the preceding month. Redding shall pay such amounts wi thin 30 days of receipt of such bill. Payments for all services provided hereunder are to be made by means of an electronic wire transfer to the following: (Electronic Wire) Attention: Cash AdministratorUnited States National Bank of Metropoli tan Branch900 S. W. Sixth AvenuePortland, OR 97204 Oregon (For credit to PacifiCorp, Account No. 070-0000-169, A.A. No. 123000220) Payments not received within such 30-day period shall be considered overdue.Beginning with the 31st day, overdue bills shall have added to them an initial charge of two percent (2\) of the amount unpaid.Each day thereafter, a charge of five hundredths percent (.05%) of the principal sum unpaid shall be added until the amount due, including the two percent (2\) initial charge, is paid in full.Payments received will first be applied to the charges for late payment assessed on the principal and then to payment of the principal.Overdue charges consisting of the initial charge of two percent (2') and the daily charge of five hundredths (0. 05\) will not exceed the highest rate allowed under applicable law. Page 27 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING precedence over deliveries which use the same transmission resources as deliveries under this Agreement and which occur under agreements which are entered into by Redding after the date of this Agreement. 10.Short-Fall Enerqy During the Exchange Period, energy deliveries associated with curtailments pursuant to Sections 10.1 and 10.2 that result in schedules of Exchange Energy below 20 megawatt-hours per hour shall be deemed Short - Fall Energy. 11.Billing 11.Firm Cacacitv and Enerav Pavment~Redding shall pay PacifiCorp each month of each Contract Year during which Firm Capacity and Firm Energy is made available to Redding as follows:The payment each month for Firm Capacity and Firm Energy deliveries pursuant to Sections 6 and 7 respectively, shall equal the sum of:(1) the price specified in Section 8. multiplied by 50 megawatts and (2) the Estimated Annual Variable Cost (expressed in dollars per megawatt-hour) multiplied by the amount of Firm Energy delivered (or required to be purchased, whichever is greater), during such month pursuant to Section 7 (expressed in megawatt-hours) with such amount being adjusted by the credit or the payment for Undelivered Power pursuant to Section 8. Page 25 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING typical weekday, Saturday and Sunday/holiday hour-by-hour schedule.Prior to 0750 hours Pacific Time each work day, PacifiCorp shall furnish a preschedule for the following day (s) showing the intended hourly schedule of San Juan energy. Redding shall make best efforts to notify PacifiCorp of any change necessary in prescheduled quantities necessitated by an operating emergency or outage and the expected duration of the operating emergency or outage.PacifiCorp shall make best efforts to notify Redding of any changes necessary in prescheduled quantities due to emergencies on its system. Real- time schedule changes should be reported to Redding at least 45 minutes prior to the affected hourly scheduli~g period and, preferably, 60 minutes prior to the affected hourly scheduling period. 10.System Loas All deliveries hereunder shall be deemed to be made during the hours and in the amounts as accounted for in Redding I s and PacifiCorp' s dispatchers' system logs; provided, that if scheduled deliveries are interrupted due to an Uncontrollable Force as defined in Section 15, such schedules shall be adjusted to reflect such interruption. the event of such interruption, Redding's schedule will be reduced on a pro rata share basis with PacifiCorp' s other firm off-system wholesale sale obligations affected by such Uncontrollable Force. Page 23 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING 10.Schedulina of Additional Enerav bv Reddina Redding has elected the Additional Energy delivery option set forth in Section 9.7 (a), the Maximum Hourly Rate of Delivery (stated in megawatt-hours and rounded to the nearest whole megawatt-hour) shall equal the result of the following equation: = Maximum Hourly Rate of Delivery310 Of f - Peak Hours Where: A Total Additional Energy Available toRedding (megawatt-hours) Provided, however, the Maximum Hourly Rate of Delivery of Additional Energy shall in no event be greater than 50 megawatt-hours per hour and PacifiCorp shall not be obligated to accept schedules of less than 5 megawatt-hours per hour. If Redding has elected the Additional Energy delivery option set forth in Section 9.7 (a), the Maximum Monthly Deli very shall equal the product of the Maximum Hourly Rate of Delivery, calculated above, multiplied by 265 (rounded to the nearest whole megawatt-hour) If Redding has elected the Additional Energy delivery option set forth in Section 9.7 (b), the Maximum Monthly Schedule of Additional Energy (stated in megawatt-hours and rounded to the nearest whole megawatt-hour) shall equal the total amount of available Additional Energy, not to exceed 10,300 megawatt-hours. Page 21 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING such San Juan Alternate Power at the highest rate PacifiCorp is then permitted to charge pursuant to PacifiCorp ' s FERC Electric Tariff, Second Revised Volume 3, or its successor tariff of general applicability.Purchases under such Tariff shall continue for a minimum of 12 consecutive months.Thereafter, Redding shall again be permitted to procure San Juan Alternate ~-r subject to Pacifi~~'s right-of-first-refusal. Power Exchanae Examcle~Appendix ~ sets forth examples of Exchange Energy. Bond Covenant Restriction (s) PacifiCorp hereby acknowledges that federal tax law imposes certain restrictions regarding the terms and conditions under which Redding is permitted to deliver San Juan energy to PacifiCorp without adversely affecting the tax-exempt status of the bonds issued by M-S-R to finance its share of the facilities comprising the San Juan generating station. PacifiCorp hereby represents and covenants that to the extent any energy exchanged by Redding under this Agreement is exchanged on a nonsimultaneous basis, PacifiCorp shall use such energy for the purpose of satisfying one or more of PacifiCorp I S peak demands.Redding and PacifiCorp agree that one manner in which the latter may satisfy the foregoing covenant is by using San Juan energy in place of hydroelectric energy to meet its then-current load and thereby continue storing water "behind the darn" for purposes of meeting Page 19 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETNEEN PACIFICORP AND CITY OF REDDING adjusted by:(a) multiplying them by a fraction whose numerator is the hourly amount of energy available pursuant to the Maximum Enti:lement following the rerating (stated in megawatt-hours) and whose denominator is 21.5 and (b) rounding the result to the nearest whole megawatt-hour) . Additional Enerav Winter Energy accumulated during any Contract Year (if any), Short-Fall Energy accumulated during such Contract Year (if any), and any unscheduled Seasonal Energy during such Contract Year shall collectively be deemed "Additional Energy;" provided, however, that any amounts of Seasonal Energy accumulated during the month of November of a Contract Year and any amounts of Additional Energy accumulated during the Season and November of such Contract Year may be carried forward to the follow~ng Contract Year. Reddina's Additional Enerav Deliv~ry OPtions Redding shall have two options for taking delivery of Additional Energy; provided that only one of these options shall apply during any Contract Year.These options are as follows: (a)Subj ect to the provisions of Section 10. Redding may take delivery of any accumulated Additional Energy : (i) on a firm basis during the months of March, April and November during Off-Peak Hours and Page 1 7 - LONG- TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING delivery of 130,000 megawatt-hours.During every hour that Uni t 4 available capacity is reduced for' other than planned annual maintenance outages, such annual obligation shall be -.J decreased by the difference between 21.5 megawatt-hours per hour and such reduced available capacity. 1.4 Additional Deliverv Riahts addition to the rights and obligations set forth in Section 3 of this Agreement, PacifiCorp shall have the right to take delivery of Power and the obligations to make Power available under the reserve sharing terms of Appendix D to this Agreement. 1.5 Schedulina Arranaements PacifiCorp shall make the necessary scheduling arrangements to take delivery of San Juan Power at the Point (s) of Delivery for the term of this Agreement and Redding's obligation to schedule such Power beyond the Point (s) of Delivery shall be accordingly eliminated. PacifiCorD Deliveries to Redding During each Season, subject to the availability of accumulated and remaining Seasonal Energy, PacifiCorp I s obligation to deliver Power to Redding, and Redding's obligation to take delivery of Power, shall be as follows: Maximum Cacacitv Deliverv PacifiCorp shall make available to Redding at the Point of Delivery 50 megawatts of capacity. Page 15 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING adjustment is a positive number, such amount shall be subtracted from Redding I s bill for such month. Exchanqes of Power Amendments to Oriainal ~areement and Exchanqe Aqreemen~ Oriqinal Aqreemen~The Original Agreement shall be hereby amended by deleting the existing provisions of Section 9. Exchanae Aqreement The Exchange Agreement shall be hereby amended by deleting the existing provisions of Sections 5.1, 5.3 and 5.4 thereof and substituting a new Section 5.1, which provides as follows: "5.Effective Date and TerminationThis Agreement shall become effective upon execution by both Parties. Service underthis Agreement shall commence at the hour ending 0100 Pacific Time on May 1, 1995 andshall terminate at the hour ending 2400 Pacific Time on November 30, 2000. 9. :2 Seasonal Exchanqe During the Exchange Period, Redding and PacifiCorp shall exchange Power as follows: Reddina Deliveries to PacifiCorp During each month of the Exchange Period, Redding' s obligation to deliver Power to PacifiCorp shall be as follows: Maximum San Juan Power Delive~ Redding shall make available to PacifiCorp at the Point of Delivery its maximum share of capacity from San Juan through a Page 13 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Prices Redding shall be obligated to pay PacifiCorp for all Firm Capacity and Firm Energy as follows: Firm CaDacity The price for Firm Capacity shall be $1, 000 per megawatt-month. 8. :2 Firm Enerqy The price for Firm Energy shall be the Annual Variable Cost. Estimated Annual Variable Cost Beginning on March 15, 1996, and on or before each September 15 thereafter, PacifiCorp shall provide to Redding the Estimated Annual Variable Cost which will be applicable for billing purposes during the following partial or whole Contract Year, whichever is applicable, in order for payments to be made on a monthly basis pursuant to Section 11. Such estimates shall be determined utilizing the best information then available to PacifiCorp.PacifiCorp shall provide, at Redding' s request, determination of the estimates. appropriate work papers and documentation supporting the Contract Year, PacifiCorp determines that the Estimated Annual If, at any time during any Variable Cost used for billing purposes during the Contract Year should be adjusted to reflect more accurate estimates, PacifiCorp shall notify and supply supporting documentation to Redding as soon as possible and shall revise the Estimated Annual Variable Cost.Said revised estimates shall be used for Page 11 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING with the FERC a letter supporting PacifiCorp' s filing of this Agreement.If the FERC does not accept this Agreement for filing in its entirety, the Parties shall exercise best efforts to amend the Agreement pursuant to Section 16 to comply with the FERC action in a manner consistent with the Parties'original intent.In the event such amendment is not executed by the Parties within 60 days, or longer if the Parties mutually agree to an extension, following the FERC's action, PacifiCorp shall withdraw its filing with the FERC and this Agreement shall terminate.In any event, if the FERC does not accept this Agreement for filing on or before May 31, 1996, this Agreement shall terminate. Firm CaDaci tv Provisions Base Amount Except as provided for in Section 6. beginning on the Service Commencement Date and continuing through November 30, 2000, PacifiCorp shall make available at the Point of Delivery, and Redding shall purchase, SO megawatts of Firm Capacity each month. action to Reduce If Redding experiences an identifiable loss of firm load, Redding's Firm Capacity obligation may be reduced by the amount of loss, to the nearest whole megawatt ("MW"), not to exceed the following limits: Page 9 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING by the Parties I schedulers and dispatchers such that no additional costs are incurred by the Parties.Point of Delivery" means for all deliveries of Exchange Energy from PacifiCorp to Redding hereunder, COB, or other points as mutually agreed upon by the Parties I schedulers and dispatchers.Point of Delivery" means, for all deliveries of capacity and energy from San Juan hereunder to PacifiCorp, at the election of PacifiCorp for any hour, Palo Verde, Westwing, Moenkopi or, subj ect to Appendix C of this Agreement, San Juan, or other points as mutually agreed upon by the Parties schedulers and dispatchers. Power" means electrical capacity and associated energy . San Juan Alternate Power" means a power resource that is substantially similar in quality and power output characteristics to the resource made available to PacifiCorp by Redding pursuant to Section 9. Season" means each period of May 1 through October 31 during the Exchange Period. 4 .Seasonal Energy" means energy available to Redding equal to the amount of energy from San Juan that PacifiCorp has, scheduled during the Contract Year in which the Season occurs (to the extent PacifiCorp I s monthly schedules have not exceeded 12,000 megawatt-hours in any month) but not to exceed the annual minimum delivery obligation pursuant to Section 9. Page 7 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING added to the Resource Pool pursuant to Appendix B, being determined by a methodology substantially similar to that see f oreh in Appendix A.-...J between the States of California and Oregon on the 500 kV California-Oregon Border" ("COB") means the boundary transmission lines known as the Pacific Northwest/Pacific Southwest A. C. Intertie where transactions between electric systems commonly occur. Contract Year" means, during the term of this Agreement, a continuous 12 -month period beginning each December 1 of each calendar year and ending November 3 0 of the following calendar year. Estimated Annual Variable Cost" means PacifiCcrp' estimate of the Annual Variable Cost, based on the best ..Jinformation available to PacifiCorp at the time such estimates are made pursuant to Section 8.3, to be used for billing purposes under Section 11. Agreement between PacifiCorp and Redding dated April 25, 1995. Exchange Agreement" means the Power Exchange Redding by PacifiCorp pursuant to Section 9. Exchange Energy" means energy made available to 2000 through the balance of the term of this Agreement. Exchange Period" means the period of December 4 . available to Redding from PacifiCorp' s total system resources. Firm Capacity" means system capacity that is made Page 5 -LONG - TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING M-S-R has a 28.8 percent (143 megawatts) ownership interest in Unit 4 of the San Juan coal-fired power project in northwestern New Mexico (" San Juan" ) . M-S-R and Tucson Electric Power Company ("TEpR) executed an interconnection agreement ("TEP Interconnection Agreement") dated September 20, 1982.Service Schedule E (dated January 23, 1985, appended as Appendix D to this Agreement) to the TEP Interconnection Agreement sets forth terms and conditions under which TEP and M-S-R share the reserve capacity and the reserve liability associated with and occasioned by their respective ownership interests in San Juan Units 1, 2 and Among other things, the TEP Interconnection Agreement provides M-S-R with reserve-sharing rights and obligations. Redding has a 15 percent entitlement in M-S-R' s rights to Power from the San Juan proj ect and rights under the TEP Interconnection Agreement. On April 25, 1995, Redding and PacifiCorp entered into a Power Exchange Agreement ("Exchange Agreement") pursuant to which Redding exchanges its share of San Juan Unit 4 capacity and associated energy, as enhanced by the TEP Interconnection Agreement, to PacifiCorp in exchange for capacity and associated energy provided by PacifiCorp to Redding. Page 3 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING LONG-TERM POIiER SALE AND EXCHANGE BETWEEN """" PACIFICORP AND CITY OF REDDING .Ereambl~~IS PO~ S~ ~ ~~~ ~E~(. Agreement"). dated this 6th ~y bet~en PacifiCo~. an O~~n co~Orati~ (.Pacifi~~.). ~dthe City of ~ddin9, a municipal co~O~ti~ o~anized ~er December 1995 is the laws of the State of California (" Redding"Pacifi~~ a~ S~etimes herein refer~d to collecti~ly a.Redding and~n~. - ~~~~U~ ~ ' ~~. EXClanatorv Recital~ PaC1fi~~ and Redding a~ OOth enga~d in genention. tnnsmission and distributi~ of electric P~r and energy . Redd1ng des1res to purcMse long-te~ capac1ty Agreement. ene~ from PacifiCo~ under the te~s and conditions of this Pactfi~~ desires to sell long-te~ ~actty a~ Agreement. e~~ to Redding ~der the te=s and conditi~s of tMs Octc~r 19, 1993, Redding a~ ~Cifi~~ entehdinto a 'Long Term POWer Sales Agreement between Pac1fiCorp and Page LONG-TER/ol POWER SALE AND EXCHANGE AGJ!EEME!IT BETIrEEII' PACIFICORP AND CITY OF REDDING LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Index to Sections Sect ion Preamble . .. .. . Explanatory Recitals Agreement Definitions Term and Termination Firm Capacity Provisions Firm Energy Delivery Provisions Prices Exchanges of Power Scheduling Billing Cost Determination Changes Audit Rights Notices Uncontrollable Forces Regulatory Impact Waiver Indemnification Dispute Resolution Amendments Assignability Page , ". !.. ~~ !I ' . ')0. ';" . , "V" , ," ,..."';". '. '.. '\ ~....'- ":h.?1'- ~' .a ')-. ....-.-....- ' , M=!Y-04-20a0 13:29. ., )~T~urr-..- ~~.~7 6905 .?1~3 Confmna.tion Agreement POD DescriptiODS . . " ALVEY 500 kV POINT OF DELIVERY Location: the point in BPA's Alvey Substation where the SOO kV facilities oIthe Panics hereto arc connected; Voltage: 500 tV; Metering: in BP A's Alvey Substation, in the Soo kV circuits over which clC:ctrlc power and energy flows; FAlRVIEW 230 kV POINT OF DELIVERY Location: the point in BP A 's Fairview Substation where the 230 tV facilities of the Parties hereto are connected; Voltage: 230kV; Meterinl: in BP A's Fairview Substation, in the 230 kV circuit over which electric power and energy flows; McNARY 230 kV POINT OF DELIVERY Location: the point in BP A 's McNary Substation where the 230 kV facilities of theparties hereto are connected; ...) Voltqe: 230 tV; Metering: in BPA's McNary Substation. in the 230 kV circuit over which electric power and encrlY flows; , ': '. -.. -, MIDWAYPOINTOFDEUVERY .. "' Location: the point in BPA's Midway Substation where the 230 kV facilities of the Parties heretO are connected; . ~ '1 ,. Voltage: 230 kV; Meterine: in BP A 's Midway Substation, in the 230 kV circuit over which electric power and energy flows: MAV-04-2000 13: 29 ~T~1B3 267 691216 19/2::: The de ratings in the following table are arranged in order of priority. from most urgent to \eaSt urgent The add screen in the AIS system will only accept these standardized NEAC event types. Event Description of Deratings - Restrictions Type lIT' ) ", '.4~~.~~n~fFC)m$~!'S tin mediate . A derating that requires an immediate1 ; r&auctiC:/nr.. ~liriaciiV. clannad rced~r, ,De ved . A derating that does not require an DZ7 immecfl8te reduction in capacity but requires a reduction in capacity within six (6) hOUTS. lanned (orc ratin - Pos ed - A derating that can be postponed beyond six hours but requires a reduction in capacity before the end of the next weekend. Mai enan erstin . A derating that be deferred beyond the end of the next weekend but requires 8 reduction in capacity before the next Planned Outage (PO). A D4 can have a flexible stan date and mayor may n~t have 8 predetennined duration. ' Plan d De . A derating that is scheduled well in advance and is of a predetermined duration. (Periodic derating for tests, such as weekly turbIne valve tests, should not be reported as PO's. Report derating$ 1or these types as Maintenance Deratincs (D4t , ". ~ .., "':,. 2 These event types are all contributors to the EFOR calculations In the reporU section. '"'~ , MAY-04-200B 13: 28 tN5FL TR '03 267 691216 17/23 Appendix B - Event Types The outages In the following table are arranged in order of priority. from most urgent to least urgent. The add screen in the AIS system will only accept these standardized NERC event typB8. Event D~scription of Outages Type nned ) Outa e - Imm diate - An outage that requires Immediate removal of a unit from service, another outage state or a Reserve Shutdown state. This type of outage- results from Immediate mechanicaVe\ectriCallhydrauTIC control svstems triDs and ocerator-initiated triDs In resconse to unit alarms. lannecl Forced) O age - Dela - An outage that does not require Immediate removal of a unit from the In.servicl state but requires removal within six (6) hours. This tIlDe of outaCle C8J1 onlY occur while the unit is in service. . Un ecl rced\ Outa . Postconed . An outage that can be po81pOft8d beyond six hours but requires that a unit be removed from the In-service stete before the end of the next weekend. This type of outage can only occur whne the unit is in service. arN FaDurl! - An outage that results trom the inability to synchronize a unit within SFI a specified startup time period following an outage or Reserve Shutdown. A startup period begins with the command to start and ends when thl unit Is synchronized. An SF begins when the problem preventing the unit 1rom aynchronlz:ing occurs. The SF ends when the unit is sYnchronized or another SF ()CCUIS. tenance Outaae . An Quta~ that can be deferred beyond the end of the next weekend, but requiAlS thBl the unit be removed from service before 1M next plann8d outage. (Characteristically, a MO can occur any time during the year. has a flexible start dete. mey or mey not have a predetermined duration and II usually much shorter than a PO. t/lalntena e Out Extension - An extension of a maintenance oUtage (MO) beyond I1s estimated completion date. This Is typically used whale the onglMl scope of work requires more time to complete than originally scheduled. Do not use this where unexpected problems or delays render the unit out of eeMoe beyond 1M estimated end date of the MO. Pla d Outa e . An outage htls scheduled well in advance and is of a predetennined duration. lasts for several weeks and occurs only once of twice a year. (Boller overhauls, turbine overhauls or Inspections are typ1c:al p1anned outaaes. ed O xtension An extension of a planned outage (PO) beyond Its estimated completion date. 'This is typically' used where 1M onglMel scope . of ,work requires more time to complete than originally scheduled. Do not use this where unexpected problems or delays render the unit out of service beyond the estimated end date of the PO. , .' '\,.. - -~ .. I These event types are aD contributors to the FOR & EFOR calcutatlons In the repolt$ ...ctlon. 05/03/00 WED 10: 10 FAX 503 813 Pac1f 1 Corp Iftheabo,y(: ref1ect~your;~iderstanding oftbe agreement reached between the . ' ~l:'l J&od1taU"o::o~f.cur o~S:i!.!li:w.iQ~.ple:lS9-&i.gr..~~te;ond r-etu:U on~fa1l-l'oXQCU~ -eop3' ...... of this Confirmation Agreement. Sincerely J TRANSALTA ENERG rTING (U. ) me. B~ Name: lS2ftN ,;? e 1?1A.1~ IaJ 005 Title:u'T\k)l\.\ 28') f~l.SCI;:J rflA-'-1 -W-. 2..0-00Date: By::FJ) --- Name: e VI b p Y' r-:- /.+ ('A IlL \T Title: (~ tJr rrJl NJJ . , t Date: (//\' y / '-Q~ a Date: " "L. , .':'''' It .. : MAV-I1I4-2BOO 13: 27 q..s~ TA'03 267 691216 P. 13/23 records and supporting documents and agree on any adjustments that may be appropriate. If the parties agree that the billing is incoITect., a corrected bill shall be p~parcd and the difference between the incorrect bill and corrected bill, including interest at shaU be paid promptly after such determination. Neither Party shan Ilnde.rtake an audit associated with billings 36~months months or older. The principal upon which intereSt rates are to be applied shall be limited to the difference between the incorrect bin and corrected bill for the 36-month period preceding the point in time that the issue was raised. PacifiCorp shall take all steps reasonably available to secure the confidentiality of TEMUS.s accounting records and supporting documents. Djsclosure of accounting records and supporting documents to PacifiCorp is not intended to. and sha11 not be interpreted to, waive TEMUS's right to deem that such records and supporting documents arc privileged, confidential, propriewy, or otherwise pro~ted from disclosure to the public. In the event such information is required in a legal or regulatory proc:c:ediD related to this Confirmation Agreement, PacifiCorp shan advise TEMUS of the requirement to disclose such information prior to disclosing it and, at TEMUS's request, shall ask for confidentiality of any such information. SeCtion 17 -Assignment Neither Party may assign their rights under this Confirmation Agreement without the consent of the other Party, which consent shall not be unreasonably withheld; movided.the non-assigning party may require additional credit related assurances which may incluck. but shall not be limited to, an irrevocable letter of credit in a fonn, amount and from a fmancial institution acceptable to the non-assigning Party. SeCtion 18 - Choice of Law To the extent that the performance, construction, interpretation OT administration of this Confumation Agreement is subject to State law, this Agreement shan be subject to the laws of the Stale ofWashiogton. l' Se.cti9n 19 - Captions and ConstnIction , ' " '. ,. . 19.All indexes, titles, subject headings, section titles, and similar items are provided for the purpose of reference and convenience and are not intended to affect the meaning of the content or scope of this Confirmation Agreement. 19.2 Every tenD and provision of this Confirmation Agreement shall be constroed simply according to its fair meaning and oot strictly for or against any Party. Section 2.0 - Partial Invalidity If any of the terms of this Confmnation Agreement arc finally held or determined to be invalid, iI1egal or void. a.11 other tenus of this ConfinnatioD Agreement shan remain in effect. If any terms are finally held or determined to be invalid, illegal or void, the Parties shall enter into negotiations concerning the terms affected by such decision for the purpose of achieving conformity with requirements of any applicab1c Jaw and the intent ~Y-04-21a0f21 13: 26 =tSI=L TA .'a3 267 6906 P. 11/23 and as necessary to fulfill the total monthly obligations of both Parties pursuant to Section Section 11 - Tvoe of Service An schedules pursuant to Section 10 for delivery to the Mid-Columbia shall be firm as defined by the WSPP Agreement for Schedule C2 (as amended or replaced) transactions. All schedules pursuant to Section ,1 0 for delivery to Paul shan be fmn for the hour of delivery as defined by the WSPP Agreement for Schedule C2 (as amended or replaced) transactions; provided, the Parties shall implement the provisions of Section 10.4 in the event of a Forced Outage or CunailmenL Unless otherwise mutUally agreed, TEMUS shall be responsible for providing all within hour reserves associated with all deliveries rn~ under this Confinnation Agreement. Section 12 - Billin~ and Pavrnent 12.1, All billings and payments associated with this ~nfinnation Agreement shall be in accordance with Section 9 of the WSPP A~ment and the Netting Agreement; l!!Pvi~TEMUS shall prepare PacifiCorp s bill each month for amounts associated with Section 7.2 by; (1) utilizing the volume weighted (utilizing actD8l energy deliveric.c; during On-Peak and Off-Peak bours "during the billing month) average of the On-Peak Index and Off-Peak Index for the billing month, minus (2) the Adjustment with (3) the application of the Cening and Floor as listed in Table B. At the end of each calendar quaner. the previous two monthly bi1lings shan be reconciled to account for the fact that the Ceilings and Floors are intended to apply on a quarterly basis as per the example calculation included in AppendixC. To the extent there are adjustments necessary due to such quarterly reconciliation. any monthly amounts owed by one Party to the other Party shal1 be adjusted for Prime from the dale TEMUS feccived such monthly paymcnt from PacifiCorp to the date of receipt by PaeifiCorp for the monthly invoice that contains such rcconci1iation. . ,, " 12.TEMUS shall transmit mon~ly invoices to PacifiCorp via .facsimile und by regular postal se-nice mail or by any such other means the Parties mutually agree uponm~~ 12.3 In the event of a conflict between the Netting Agreement. the WSPP Agreement, or the Confmnation Agreement, any such conflict shall be l'C5olved by rde~ncc to the teons contained in such agreements in descending order of importance as foUows: this Confmnanon Agreement, the Netting Ap:ement, the WSPP AgrecmeoL Section 13 - UQ).1idated Dama~ In the event TEMUS fails (0 meet its minimum delivery obligation hereunder, or. PacifiCorp faits to take receipt of any deliveries, as provided for hCTein, me liquidated damages contained in Section 21.3 of the WSPP Agreement shall govern. PacifiCorp shall operate its electrical system pursuant to Prudent Electrical Industry Practice. TEMUS shan assure that Centralia is operated pursuant to prudent Electrical Industry ~Y-04-2000 13:25 t:s:l. T A .J3 267 6986 P . 89/23 TEMUS shall pre-sch~dule 300 MW/hour to PacifiCorp at Paul, unlcss modified pursuant to Sections 10.5 or 10.6, for the time period June 1, 2001 through June 30, 2002, by 0900 hours PPT on the mutually recognized pre-scheduling business day prior to the day(s) of deli veT)'; provided, TEMUS shall be able to reduce such scheduled amounts no later than 3Q-minutes prior to the hour of delivery in the event of a Forced Outage or Curtailment; movided further, TEMUS shall have the obligation to increase any such reduced scheduled amounts, by ,giving PacHiCorp notice no later than 30-m.inuteS prior to the hour of delivery, when the event of Forced Outage or any portion of a Curtailment event ends unless deliveries are taking place pursuant to Section 10.4 in which case deliveries shall resume at HE 0100 on the day immediately following the day that schedules pursuant to Section 10.4 end. 10.To the extent Ccntralia is Available, or anticipated to be Available, TEMUS shall schedule 400 MWlhour to PacifiCorp at Paul. unless modified pursuant to Sections 10.5 or 10.6, for the time period July 1. 2002 through June 30, 2007, by 0900 hours PPT on the mutually recognized pre-scheduling business day prior to the day(s) of d~livery; provided, TEMUS shall be able to reduce such scheduled amounts no later than 30-minutes prior to the hour of delivery in the event of a Forced Outage or Curtailment; provided further.TEMUS shall have the obligation to increase any such reduced scheduled amountS. by giving PacifiCorp notice no later than 30-minutcS prior to the hour of deUve.ry, when the event of Forced Outage or any portion of a Curtailment event ends unless deliveries arc taking place pursuant to Section 10.4 in which case deliveries shall resume at HE 0100 on the day immediately following the day that schedules pursuant to Section 10.4 end. 10.TEMUS shall have the obligation to schedule and deliver a minimum amount of energy each month to PacifiCorp. pursuant to the terms of Sections 10. t. 10. 10.4. 10.S, and 10.6, equal to; (1) the hourly amountS provided in the applicable Sections 10.1 or 10.2 multiplied by (2) the number of hours in the applicable month multiplied by (3) 0.94. ~1:~;" ~ ' 10.Upon the. occurrenCe of aPlant,Contingency. 1'BMUS s\i~~1 1C~jse its Paul delivery schedule pursuant to the terms of the applicable Section 10.1 or 10.2. For the duration of the Plant Contingency, TEMUS shall have the right to make deliveries to PacifiCorp at Mid-Columbia as described in this Section 1 O.TEMUS shall be obligated to provide PacifiCorp s pre-schedulers, by the later of 0700 hours PPT following the Plant Contingency or 5-hours following the Plant Contingency, with the expected duration of the Plant Contingency and the delivery day and delivery amounts that TEMUS intends to schedule to PacifiCorp at Mid-Columbia; provided.eny Mid. Columbia ddiveries scheduled pursuant to this Section 10.4. unless TEMUS schedules in rca1-time pursuant to Section 10.1. shall be pre-scheduled by 0700 hours PPT on the mutually recognized scheduling day prior to the day(s) of delivery; provided further,such Mid-Columbia schedules shall be in twenty four equal hourly amounts as dete11Irlncd by the difference between the hourly amounts pursuant to Sections 10.1 or 10.2, as applicable (unless modified pursuant to Sections 10.5 or 10.6) and the reduced hourly schedule at Paul due to the Plant Contingency. TEMUS shalt ha'Ye the obligation to continue such Mid-Columbia schedules through the longer of the duration of the Plant ... 5~TA '1 267 6906 0?/23 2004 22. 2004 44. 2004 34. 2005 29. 2005 22. 2005 45. 2005 34.58 2006 30.16 2006 22.5 1 2006 45. 2006 34. 2007 30. 2007 22. For the wne period June 1,2001 through June 30. 2002. PacifiCorp shall pay TEMUS each month. associated with (1~OI300)% of the energy delivered and received each month; (llthe energy rate equal to the volume weighted (utilizing lICtUal . energy deliveries during On-Peak and Off-Peak bOUTS during the calendar quarter) avenge of the On-Peak. Index and Off-Peak Index for the calendar quarter in which the billing month faUs, minus (2) the Adjustment with (3) the application of the Ceiling and Floor as listed in Table B below. FOt the time period July 1. 2002 through June 30. '1IXf1. PacifiCorp shall pay TEMUS each month, associated with (150/400)% of the energy delivered and received each month; (1) the energy rate equal to the volume weighted (utiJj:z.ing actual cner!)' dcJjveries during On-Peak and Off-Peak hours during the calendar quarter) average of the On-Peak Index and Off~Peak Index for the calendar quarter in which the billing month falls, minus (2) the AdjUstment with (3) the application of the Cei1ing and Floor as listed in Table B below. An example calculation is included in , ' ,.r , . :' Apppdix A. ' . . ' ~'r'-e4-2~ 13:25 . , Year 2001 53.30. 2001 47.25.1.50 2002 43.22.SO 2002 37.14. 2002 60.36. 2002 49.26.1-'0 2003 43.22.1.50 uarter March MAY-I1I4 21!10e 13: 24 403 2E.7 6906TnCfIS=L TI=I . amOUI)t5 on a pro-rata basis for the appHcabl~ hour. A Plant Contingency shall not include a Maintenance OutagcJDerate. Uncontrollable Force" shall have the same meaning as defined in the WSPP Agreement; provided. pursuant to Section 10.1 of the WSPP Agreement. the. parties hereby agree that the firm contractual transmission path being utilized by PacifiCorp to transmit Panl deliveries hereunder sha11 be the FPT ContraCt. Notwithstanding the foregoing, termination or assignment of the FPT Conuact for any reason shall not be considered Uncontrollable Force. Section 2 - Tenn & Termination Subject to the receipt of the approvals provided for in Section 3. this ConfinnatioD Agreement shall become effective ("Effective Date ) upon its executioD by both Parties. Unless mutua1Jy agreed otherwise. deliveries contemplated hereunder shall begin on JUDe 2001. This Confmnation Agreement shall terminate at HE 2400 on June 30, 20(f1. Applicable provisions of this Confmnation Agreement shall continue in effect. after termination to the extent necessary to satisfy the terms and conditions of this Confinnation Agreement and. as applicable, to provide for final billings and adjustments related to the period prior to termination and payment of any money due and owing either party pursuant to this Confirmation Agreement. Section 3 - Regu1atolj' Aporovals If required by FERC. TEMUS shal1 me this Confinnation Agreement with FERC within lo-days of its execution by both Parties or when otherwise required by the FERC to be ftled, whichever is later. If the FERC dou not issue. an order accepting this ConfU1T1ation Agreement for filing in its entirety and without change, the Parties shal1 exercise best efforts to amend the Confirmation Agreement to comply with the PERC order or negotiate a repl~ment agreement providing similar benefits to both Parties within 6O-days following FERC's issuance of such order. In the event the Parties are not able to negotiate a replacement agreement. the Parti~ a&i=. to submit to the arbitration proceduru contained in the WSPP Agreement in order to determine the termS and conditions of a replacement agreement that complies with the FERC order. :;ection 4 - De-liven Rate and Contrad Ouantlb' For the time period June 1, 2001 through JuDe 30, 2002, PacifiCorp shall purchase and TEMUS shall seU, 300 MW. as scheduled pursuant to Section 10. each month at a minimum monthly load factor of 94%. based on all hours of the month, and a maximum monthly load faCtor of 100%, based on all hours of the month. TEMUS shall be obligated to deliver the minimum monthly load factor notwithstanding Forced Outage. Curtailment. Maintenance OutageJDerate, or Economic Displacement during such month. For the time period July I. 2002 through Junc 30, 2007. PacifiCotp shall purchase and TEMUS shall sell, 400 MW. as scheduled pursuant to Section 10. each month at a minimum monthly load factor of 94%, based on all hours of the month, and a P . OS/23 - 0 \ ". ',. '. ~ ........, MAY-04-2000 13:23 - ~~TA'1 267 6906 P .1a3/23 Ccnt:ral1a" means the Centralia generation plant located near Centralia, Washington that has a nameplate generation capability of 1, 340 MW produced by two separate generation units. Curtaihnent" means a reduction in Centralia generation capability due to an unplanned forced de-rating, on either, or both, Centralia unites), as categorized by standardized NERC event typeS Dl (immediate), D2 (delayed), or D3 (postponed). Economic Displaceme~t" or "Economically Displace" means any hour that the generation capability of CentraHa is reduced due to economics or due to NERC' definition of a NC (non-curtai1ing) event The rcciuction of generation capability in .order for TEMUS to bid ancillary services to an independent system operator, such as the California Independent System Operator, shall not constitUte . Economic Displacement. Effective Date" means the date that both Parties execute this Confirmation Agreement and the receipt of FERC acceptance pursuant to Section 3. 'F100r" means the minimum SIMWh quarterly price for energy as applied pursuant to the methodology in Section 7.2 and as listed in Table B. FPT ContraCt" means PacifiCorp s BPA contraCt #14-t)3-09228. 'The FPT Contract provides fnm transmission service for PacifiCorp from Pau1 to various points of receipt on PacifiColp S system, across the BPA tranSmission netwmt. ~on:ed Outage" means a reduction in Centralia generation capability due to an unplanned forced outage on either Centralia unit as categorized by standardized NERC event typeS 01 (immediate), U2 (dclaycd), U3 (postponed), or SF (startUp failure). IIB" means hour ending. Maintenance OutageJDe.rate" means a reduction in Centralia generation capability due to a planned maintenance de-ratlng OT outaF as categorized by standardized NERC event typeS MO (maintenance outage), ME (main~nance outage extension). PO (planned outage), PE (planned outage extension), D4 (maintenance derating), or PD (planned derating)'- 'Netting Agx=ment" means the Mutual NettinglSeulements Agreement betWeen the Parties, dated January 1. 1999, as amended. NERC" means the North American Electric: Reliability Council. ... ' POWER EXCHANGE AGREEMENT BETWEEN PACIFICORP AND THE CITY OF REDDrNG Preamble:THIS POWER EXCHANGE AGREEMENT ("Agreement"), dated this .(' 5'~a y of April 1995, is between P acif iCorp . an Oregon Corporation, and the City of Redding, a municipal corporation organized under the laws the state California ("Redding" ) . PacifiCorp and Redding are sometimes referenced hereinafter collecti .ely as Parties"and individually "Party. " ExDlanatorv Re~itals MSR has a 28.8 percent (143 MW) ownership interest Unit the San Juan coal- fired proj ectpower northwestern New Mexico. t::"...- Service Schedule E (dated January 23, 1985, appended as Exhibit A to this Agreement)the TEP Interconnection Agreement, sets forth terms and conditions under which TEP and MSR share the reserve capacity and the reserve liability associated with and occasioned by their respective ownership interests in San Juan Units 1, 2, and 4.Among other things, the TEP Interconnection Agreement provides MSR with reserve- sharing rights and obligations. .., ":2 .;.. ... Redding has a 15 ~ercent entitlement in MSR' s rights to Agreement. " Cal i f ornia - 0 regon Borderll (COB)themeans boundary between the states of California and Oregon. II Existing Agreement" means the Long-Term Power Sales Agreement between PacifiCorp and Redding, dated October 19,1993. FERC" means the Federal Energy Regulatory Commission. GWh" means gigawatt-hour, a unit of electrical energy. "Maximum Entitlement"Redding'means percententitlement (15 percent of MSR's 28.8 percent entitlement) to San Juan Unit 4 energy production. MSR"the M-S-R Public Power Agency,means Joint Exercise of Powers Agency duly organized under the laws of the state of California and consisting of the Modesto Irrigation District, the City of Santa Clara, and the City of Redding. MW" means megawatt, a unit of electrical capacity. MWh" means megawatt-hour, a unit of electrical energy. Powerll means electrical capacity and associated energy. FERC's action, either Party shall have the option to terminate this Agreement upon thirty days ~ri t ten notice to the other Party.In such event, any liabilities accrued between the effective date of this Agreement and the effective date of termination, inclusive, shall remain intact. Earlv Termination Bv Reddina:Redding shall have the right to terminate this Agreement upon four months'priorwrittennotice,provided that shallevent any termination under this Agreement be effective prier to the hour ending 2400 Pacific Time on September 30, 1995. Earlv Termination Bv PacifiCorc:PacifiCerp shall have the right to terminate this Agreement upon ene year's prior written notice. Point (s) of Delive~ Deliveries to PacifiCorc:Power delivered by Redding or its agent (s) pursuant to this Agreement shall be delivered to PacifiCorp at the Palo Verde, Westwing, Moenkopi, or San Juan delivery points (as designated at any time (subject to the provisions of Section 8 of this Agreement) by PacifiCorp), or as otherwise mutually agreed by the Parties.'!'he delivery of such Power to PacifiCorp shall be in accordance with Section 7 of this Agreement. ;'" - o. ~Deli ~eries to Reddina:Power deli versa by PacifiCorp to being scheduled by PacifiCorp for that hour. Minimum Deli v'eries:During each hour in which San Juan Unit 4 is operating,PacifiCorp shall have the obligation to take delivery of a minimum of 9 MWh/hr. During times when Unit 4 is unavailable, this obligation shall become zero. Enerqv Deliveries:The following energy delivery provisions shall apply: 7 .1. 4 . 1 Beginning with the commencement of service pursuant to Section 5 .this Agreement and ending December 31,1995,inclusive,Pacif1Corp shall have the right to take delivery of up to Redding's Maximum Entitlement.During that same time period, PacifiCorp shall have the obligation to take delivery of the lesser of (1)Redding' Maximum Entitlement, or (2) 86.7 GWh of San Juan Unit 4 energy, provided that this obligation shall be reduced by an amount equal to the reduction in Redding's Maximum Entitlement caused by partial or complete forced outages. Each calendar year thereafter, PacifiCorp shall have the right to take deli .J'ery of up to Redding'S Maximum Entitlement.During those same :~me periods, PacifiCorp shall have che obligation . . sharing terms of Exhibit A to this Agreement. 7 .Paci:iCorn Deli';eries to Reddinq:Energy delivered by Redding to PacifiCorp from San Juan shall be exchanged for energy to be delivered by PacifiCorp to Redding under the Existing Agreement accordance with the following methodology : PacifiCorp shall deliver an amount of energy to Redding equal to the amount of San Juan energy delivered to PacifiCorp multiplied by 1.372 provided that. during any calendar year,for any San Juan Unit, 4 energy delivered to PacifiCorp in excess of the minimum amount derived pursuant to Section 7 .4 of this Agreement. the aforementioned 1.372 shall be reduced to 1.100 (or lower as mutually agreed from time to time by the Parties) . Redding's obligation to take delivery of energy under the Existing Agreement shall be reduced by the greater of the amount derived in Section 7.1 of this Agreement or the amount derived in Section 7 .4 of this Agreement multiplied by 1.372. PacifiCorp'obligation to deliver energy Redding under the Existing Agreement shall be reduced by the amount deri 7ed in Section 7.1 of this Agreement. The accounting associated 'l1it.h the foregoing provisions of and/or notification obligations to other parties.On an ongoing basis during the term of this Agreement, Redding shall use best real- timeeffortsfacilitatePacifiCorp' scheduling and system operation requirements (e. g., timing anddirect communications with other entities associated with Redding'San Juan resource)they pertain this Agreement.To the extent the aforementioned obligations are mitigated for Redding,Redding shall use best efforts to provide commensurate relief for PacifiCorp. Audit: Riaht:s:The Parties, at their own expense, shall havethe right to audit and to examine any operating and/orfinancialdatarelateditemanyforthsetthis Agreement.Any such audit shall be undertaken by the auditing Party or its representatives at reasonable times and. in conformance with generally accepted auditing standards.The right to audit any information shall extend for a period of five years following the transaction to which such infox:ma.tion pertains under this Agreement.Both Parties fully agree to cooperate with such audit and to retain all necessary records or documentation for the entire length of the audit period. Both Parties shall take all steps reasonably available to secure the confidentiality of each other' s accounting records and supporting documents.If any such audit discloses that any discrepancies as to the intent of this Agreement, both Parties hereby agree to attempt to remedy such discrepancy in an expeditious manner. 12. obligation hereunder :.: failure of performance shall be due toan Uncontrollable Force.The term "Uncontrollable Force" means any cause beyond the control of the Party affected, including, but not limited to, failure of facilities, flood,tsunami, earthquake, storm, fire, lightning, epidemic, war,riot,civil disturbance,labor disturbance,sabotage,andrestraint by court order or public authority,which,exercise of due foresight,such Party could not reasonably have been expected to avoid;and to the extent that by exercise of due diligence,it shall not have been able overcome.Party shall however,not,relieved ofliability for failure of performance to the extent such failure is due to causes arising out of its own negligence or to the extent such failure is' the result of removable' or remediable causes which it fails to remove or remedy with reasonable dispatch. Any Party rendered unable to fulfill any obligation by reason of an Uncontrollable Force shall exercise due diligence to remove such inability with all reasonable dispatch and shall notify the other Party such Uncontrollable Force soon practicable.Nothing contained herein, however,shall be construed to require a party to prevent or settle a strike against its will. Requla tOry Modi fica ti on:In the event that subsequent to the approval referenced in Section 5.2 of this Agreement, the FERC or any agency or court of competent jurisdiction materially modifies any term or condition of this Agreement in such a ;nanner that either Part'l is required to incur new or different """!\ .,.... ..., Energy Purchase Original to Central files - 550 LCT Copied for Confirm Files Dea~ No. 326704. Apri.1 20, 2000 Enron Power Marketing, Inc. P. O. Sox 4428 Houston. Texas 77210-4428 (FAX) (713) 646-2491 '" . " \L' Paul. Wood Paci.fi.corp 9951 SE AnkenyPortl.and , OR 97216 Fax No.(503) 256-6168 C ONF IRMA':r I ON IE ':r ':IE R Thi.s letter shall. confirm the agreement reached on Apri.l. 20, 2000 betweenPaci.fi.corp and Enron Power Marketi.ng, Inc. ("EPMI") regarding the sale of Fi.:cD Power under the terms and condi.t.i.ons that follow: / Seller:Enron Power Marketing, Inc. Buyer:Paci.f i.corp Term:~nday, January 1, 2001 through Fri.day, December 31, 2004.Hour Endi.ng (HE) 0700 through HE 2200 (16 Hours each day), Monday through Saturday only, excl.udi.ng NERC Holi.days;Paci.fi.c Prevai.ling Ti.me. Type of Commodi. ty :Fi.rm Power Pr~ce :US Dol.l.ars $41. 50/MWh. Quan t~ ty:25 Hws of Firm Power per hour. Deli.very Point(s) :COB N/s Scheduling: EPMI Real Time Operati.ons: 1-800-684-1336 Firm Power is power that i.s or wi.ll be scheduled in accordance wi. th Appli.cableReserve Requirements for whi.ch the only excuses for fai.lure to deli.ver or rece~ve are if an interrupt~on is (i) due to an Uncontrollable Force as provi.ded~n Secti.on 10 of the Agreement; or (i.i.) where appli.cable, to meet Sel.1er publi.c uti.li.ty or statutory obl.i.gat.i.ons to i.ts customers. If Sel.l.er exerci.sesits ri.ght to interrupt to meet its publ.i.c ut.i.li.ty or statutory obl.i.gati.ons, Seller shall be responsible for payment of damages for fai.l.ure to del.~ver Fi.rm Power as prov~ded i.n Sect~on 21.3 of the Agreement. Appli.cable Reserve Requirements" means WSCC operating reserves. D-l No. 326704. Thi.s confi.rmati.on l.etter i.s bei.ng provi.ded pursuant to and i.n accordance wi.th Western Systems Power Pool. Agreement ("WSPP Agreement"), as amended peri.odi.cal.l.y wi.th FERC approval., to whi.ch Paci.fi.corp and EPHI are parti.es. Terms used butnot defi.ned herei.n sha1l. have the meani.ngs ascril::led to them i.n the WSPP Agreement. Pl.ease confi.:aa that the terms stated herei.n accuratel.y refl.ect the agreement reached on Apri.l. 20, 2000 between you and EPHI by returni.ng an executed copy ofthi.s l.etter by facsimi.l.e to EPHI at (713) 646-2491. Your response shoul.d refl.ectthe appropri.ate party i.n your organi.zation who has the authori.ty to enter i.ntothi.s transacti.on. If you have any questi.ons pl.ease cal.l. (713) 853-1886. Paci.fi.corp Enron Power Harketi.ng, Inc. By:By:I iSJ.L. Name::::II. Y D .\!lU_ ::.~ lRECTOR. \liD-OH;ii::~ Name: ':rim Bel.den Title:Title:Vi.ce Presi.dent ~'- MAY-04-2000 13: 23 TRANSj:L TA 403 267 6906 P . 1112/23 May 4. 2000 Terry Hudgens. Senior Vice PresidentPacifiCorp 825 N.E. Multnomah, Suite 2000 portland, (negon 97232 Dear Mr. Hudgens: pacifiCorp and TransAlta Energy Marketing (U.) Inc. ("TEMUS") are both Parties to the version of the Western Syst.cIIl5 Power Pool Agrument, effective February 1.2000 WSPp Agreement"). This Conf1I1l1ation Agreement ("Confmnation Agreement'") setS out the understanding reached betWeen the representatives of our organizations concerning the sale of energy by TEMUS to PacifiCorp under the termS and conditions of the WSPP Agreement and Service Schedule C (rum energy - C2 as amended or replaced). both as supplemented and modified below. TEMUS and PacifiCorp are individually referred to herein as a "Party" and col1ectively as the "Parties S,.ection 1 - ~finitions 24-Hour Index" means the Dow Jones'"" Telerate Mid-Columbia 24-HoUI Fl11D. electricity index for the applicable Sunday or NERC holiday of dellVeI)'. At the , present time, Dow Jones definas the delivery schedule for the 24-Hour Index at the Mid-Columbia as twcnty-four (24) continuous hours on sundays iod NERC holidays. ~ '.. Adjustm~nt" means the $/MWh adjustment to be applied pursuant to the methodology in Section 7.2 and as listed in Table B. Available" means, for any hour. the Centralia capability of generating electricity up to its rated capacity less amounts due to a Plant Contingency. BP An means the Bonneville Power Administration. Ceiling" means the maximum $IMWh quarterly price for energy as applied pursuant to the: methodo1ogy in Section 7.2 and as U&tcd in Table B. MAY-04-2000 13: 24 TRt=."'S1=L TA 4133 267 6906 B4/23 On-Peak" means the delivery schedule as defined by tl)e On-Peak Index for Monday through Saturday, excluding NERC holidays. On-Peak Index" means the Dow Jones'l'M Te1eratc Mid-Columbia Firm On-peak elGCtricity index for Monday through Saturday, excluding NERC holidays, days of delivery. At the present titne, Dow Jones defines the on-peak delivety schedule for Mid-Columbia as HE 0700 through HE 2200. Off-Peak" means the delivery schr.dule as defined by the Off-Peak Xndex for Monday through SatUrday and the delivery schedule as defined by the 24-Hour Index for Sunday and NERC Holidays. Off-Peak Xndex" means the Dow Jones TM Tclerate Mid-Columbia Firm Off-peak electricity index for Monday through Saturday days of delivery and the 24-Hour Jndex for Sundays and NERC holidays. At the present time. Dew Jones defines the off-peak delivery schedule for Mid-Columbia a." HE 2300 through HE 0600 for Monday through Saturday. PacifiCoIp s System" means the points of interconnection between PacifiCorp Western control area and the BPA's transmission network such that PacifiCorp is able to import up to the amount being scheduled by TBMUS pursuant to the provisions of Section 10.6. PacifiCorp s System shall be comprised of the points of delivery as shown in Appendix D. Paul" means the point of interconnection between Centralia and BPA at the Soo kv bus of BPA"s Clm:nce W. Paul Substation. PPT" means Pacifi~ prevailing time, whether standard or daylight savings, that is jn effect on any given day. Prime" means the t.ime-weightcd prime inte~t rate as established by the Morgan , Guaranty Trust Company of New York. \ ~ ' ". '~ --, " Prudent E1cctrica1 Industry Practice" means those practices, methods. and equipment. as changed from time to time, that; (1) when enpged in are commonly used in prodeot electrical engineering and operations to operate electric equipment lawfully and with safety, reliability, efficiency. and expedition; or (2) in the exercise of reasonable judgment considering the facts known when engaged in, could have been expected to achieve the desired result consistent with applicable law, safety, reliability, efficiency, and expedition. Prudent Electrical Industry Practice is not limited to th~ optimum practice, method, selecdon of equipment, or act, but rather is a range of acceptable practices. methods, selections of equipment. or acts. Plant Contingent" or "Plant Contingency" means an event of Forced Outage or Curtailment that reduces TEMUS's ability to meet its schedules hereunder at Paul for the next schedule hour, provided, TEMUS shall allocate any Curtailment rAY-04-2000 13: TR~I=L TA '403 267 6906 P . 06/23 maximum monthly load factor of 100%, based on all hours of the month. TEMUS shall be obligated to deliver the. minimum monthly load factor notwithsWlding Forced Outage, Curtailment, Maintenance OutageJDerate, or Economic Displacement during such month. Section 5 - Delivery Point The delivery point for deliveries associated with Section 10.1 and Section 10.1- shall be Paul unless moved to the Mid-Columbia or PacifiCorp s System pursuant to the provisions of Section 10. Section 6 - Creditworthiness The Parties agree to utilize the creditWorthiness tenns and conditions pursuant to Section 27 of the WSPP Agreement. Section 7 - Contract Price The contractual price for all purchase-.. hereunder shan be the summation of Sections 7.1 and 7. For the. time period June 1,2001 through June 30, 2002, PacifiCorp shall pay TEMUS each month a fixed dollar amount per MWb as provided in Table A below for (150/300)% of the energy delivered and received each month. For the. time period July 2002 through June 30, 2007, PacifiCorp shan pay TEMUS each month a fixed dollar amount per MWb as provided in Table A below for (250/400)% of the energy delivered and received each month. Month March Janu , March Year 2001 2001 2001 2002 29. 2002 21. 2002 43.10 2002 33. 2003 29.5.5 2003 21. 2003 43. 2003 33. 2004 29. , ', '~.. .~~)-.. . MAY-04-2000 13: 25 TR~TI=I 403 2E.? 6906 P .1118/23 A"ril. May. June 2003 38.18 14.1.50 Jolv, Aurost, September 2003 61.73 36.1.50 October, November, December 2003 49.26.1.50 Januarv. February, March 2004 44.22. APIi1. Mav. June 2004 38.15.1.50 July. AugUSt, SePtember 2004 62.37.1.50 October, November, December 2004 50.27.1.50 Januarv. Februarv. March 2005 44.22. ADril, May. June 2005 38.15.37 1.50 Julv, Au~st, SePtember 2005 63.38.43 1.50 October, November, December 2005 50.27.1.50 JanoBfV, Februarv. March 2006 44.41 23.16 ADril. May. June 2006 38.15.1.50 Julv. August, September 2006 63.38. October. November, December 2006 51.00 27.1.50 JanuarY. February, March 2007 44.23.1.50 Aunl. Mav, June 2007 38.15.1.50 * - June through September shall be considered a quarter for this time period and adjustments pursuant to Section 12.1 shan place on a 4-month quarter. Section 8 - NERC Event Tvoes The NERC event types ~fcrenced herein are attached as Appendix B. To the extent NERC modifies, de-Ietes, or adds new event types, the Parries shan use best efforts to agree upon the catego~atipn of such modified or added event type pursuant to the definitions contained in Appendix B, the intent of the Parties as' of the Effective Date, BIld the definitions of Curtailment, Forced Outage. and Maintenance Outagc:lDerate contained herein. To the extent the Parties are unable to agree upon the categorization of 8 new or modified event type, the Parties shall utilize the dispute resolution procedures containedin the WSPP Agreement. . ~ .. Section 9 - Loss of Index In the event the On-Peak and/or Off-Peak Index and/or 24-Hour Index is no longer reported, the Parties shall flJ'St attempt to negotiate a ~placement index. In the event a replacement index is not agreed to within 3O-days of the fust written offer by either Party, the Parties shall then utilize the dispute resolution procedures contained in the WSPP Agreement ~ectlon 10 - Schedulin, 10.To the extent Centralia is A van able. or anticipated to be Available, ,. ~ MAY-04-2008 13: 26 TR~~ TA .P. 10/234(33 267 691116 Contingency or the schedule day(s) for which TEMUS has pre-schedu1ed such Mid- , Columbia deliveries to take place. 10.4.1 TEMUS may begin Mid-Columbia schedules contemplated in Section 10.4 by giving PacifiCorp no less than 4-hours notice prior to the hour of delivery on the day in which a Forced Outage or Curtailment takes place; provided any such schedules begun pursuant to this Section 10.4.1 shall continue in the amounts and for the duration of the Forced Outage or Curtailment, and as otherwise provided for. in Section 10.4~ 10.If TEMUS is able to predict a Maintenance OutagelDeratc 3o-days in advance, TEMUS shaH have the option to pre-schedule any portion of its obligation pursuant to Sections 10.1 or 10.2 to PacifiCorp at the Mid-Columbia (rather than at Paul), by 0900 hou~ PPT on the mutUally recognized scheduling day prior to the day(s) delivery; provided, such schedules shan be firm pursuant to the WSPP Agreement (schedule C2 as amended or replaced) and such schedules shall be for an equal hourly amount for the entire period of Maintenance OutageJDerate; mPvided further.TEMUS shall notify PacifiCorp s ~-schedulers in writing no less than 30-days prior to the period in whichTEMUS wishes to utilize the provisions of this Section 10.5 and such , ' notification shall include a description of the upcoming Maintenance OutagelDcra.te event and its anticipated duranon. Schedules pursuant to Sections 10.1 or 10.2 shall resume on the first schedu1e day following the end of the Maintenance OutagclDerate event contemplated in this Section 10. 10.In the event TEMUS wishes to Economically Displace Centralia. ,TEMUS shall have the option to pre-schedule any portion of its ob1i&ation pursuant to Sections 10.1 or 10.2 to PacifiCorp at Paul or PacifiCorp s System, by 0700 hours PPT on the mutually recognized scheduling day prior to the day(s) of dClivery; provided, sucb schedules shall be finn pu~uant to the WSPP Agreement (schedule C2 as amended or replaced) and such schedules for each point of delivery shall be for an equalbourly amount for either the On-Peak or. Off-Peak bours of the applicablc;Clay. Schedules pursuant to Sections 10.1 Or 10.2 shall resume on the first schedule 'day following the end of the Economic Displacement; provided, during the period of Economic Displacement, TEMUS shall not be precluded from increasing its Centralia generation level during any given generation hour due to the need to supply operating reserYes for its control area operator under a reserve sharing pool arnmgement. provided further, in the event TEMUS wishes to increase the Centratia generation level during any given hour due to updated market economic situations then TEMUS shaH curtail its schedules to PacifiCorp System, nO later than 3o.-minutes prior to the hour of delivery, and shall resume such 8chedulcs at Paul pursuant to Sections 10.1 and ) 0.2. In the event TEMUS schedules to PacifiCorp at Paul pursuant to this Section 10.6, and BP A denies such schedules at Paul because such generation schedules are not sourced from CentraJia, then TEMUS shall utilize PacifiCorp s System as the point of delivery. ' . "~:~~~~ ;..-a...o.A.. 10.Notwithstanding Sections 10.1, 10.2. 10.4, 10.5, or 10.6 the Parties' pre- schedulers or dispatchers may mutually agree upon delivery hours, delivery rateS, or . points of delivery that are different than the provisions of this Confumation Agreement MAY-ta4-2000 13:27 TR~1=l. TA .403 267 6906 12/23 Practice. Section 14 - Noti~ 14.AIl notices and correspondence associated with this Confinna1ion Agreement shall be sent to the following; To TEMUS:TransA1ta Energy Marketing U.S. Inc. Attention: Legal Department Box 1900, Station u 1l0-121h Avenue S. Calgary, Albena TIP 2Ml To PacifiCorp:PacifiCorp Sr. Vice President, power Systems 9951 S.B. AnkenyStrcet Portland, Oregon 97216-2315 With a copy to:PacifiCorp Manager, Contract Administration 9951 S.E. Ankeny Street Portland, Oregon 97216-2315 14.TEMUS shall contact PacifiCorp s real-time dispatChers as soon as possible foHowing an ~vent of Forced Outage or Curtailment, and as soon as TEMUS able to predict when a Forced Outage or Curtailment may occur, by calling PacifiCorp real-time desk at 503-251-5222 or 503-251-5224 with an additional notification to PacifiCoxp s pre-schedulers as soon as practicable. TEMUS shall use best reasonable effortS to increase or reduce schedules pursuant to the tenus of Sections 10.1 or 10. before 30-minutes prior to the hour of delivery.'11. .?-t, " ..:...~; ~ 'f ....-~ '--,~ .. Section 15 - Priciu2 MethodoloEV The pricing containcd in Section 7 shall remain in effect through the term of this Confirmation Agreement and n~ither Party shall petition the FERC pursUBJIt to the provisions of Section 205 or 206 of the Federal power Act to amend such prices absent the agreement in writing of the other. Party. ~ection 16 - Audit RiEhu PacifiCoxp, at its own expense, may rcvi~w TEMUS's accounting records and supporting documents, including but not limited to the NERC event coding of any event(s) associated with Centralia. of any bi11ing associated with this Confirmation Agreement. PacifiCorp shalt schedule such reviews at Jcast fourteen daY6 in advance BJld at times considered to be normal business bours by TEMUS. If either Party beljcves there are any errors in the detennination of a bill, including prices, PacifiCorp sha11 withhold payment of the disputed amount and the Parties shan meet to review the accoun:ting MAY-04-2000 13:27 TR~~ TA'403 267 6906 of the Parties. SeCtion 21 - Countetparts The parties may execute and de1iv~r this Confirmation Agre~mcnt by executing a counterpart page hereof and delivering it, whether by facsimile device or othetWise. to the other party and the production of such an executed counteJPart page is sufficient for all purposes of evidencing due execution and delivery of this ConflI1I1ation Agreement by a party. Section 22 - Uncontrollable Force - , 22.In the event that an Uncontrollable Force prevents the gmeration and delivery the applicable full contract quantity as specified in Sections 4.1 or 4.2 from Centralia for a continuous period of six (6) months or greater. a) during such initial six-month period. TEMUS shall only be liable to PaciflCorp for Hquidated damages as provided for Section 13, without limitation in amount; b) following such initial six-month period.. TEMUS shall only be liable to PacifiCorp for liquidated damages as provided for in Section 13, provided that TEMUS. total net liability for liquidated damages to PacifiCorp for such non-delivery duling the period following such initial six-month period shall not exceed S. S83,OOO.0QQj; and (c) at any time after the end of such initial six (6) month peno and continuing until the re-commcncement of delivery of the applicable full contract quantity as specified in Sections 4.1 or 4.2 from Ccntralia. PacifiCorp shall have the right to suspend its right and obligation to mak~ power purchases under this Confirmation Agreement without funher liability. , 22.In applying Section 22.1, the tenn "Uncontrollable Force" shan not include: (8) a Centralia outage related to the installation or testing of pollution control equipment; or (b) a curtailment of Centralia required by governmental authority as a \ result of a failure to install ~r :roperty operate required pollution control devices. Ik ;"cM(I!OvlCe '&( ...1;c:. '- fu.-f& powtr lkr~ 0 /.:;/;1 ~ f-;~J UAIldu- fftM -hrtl,ud:'1N\ fhle~j- would f-,e..nn/~il .Je; pJ-~ rft!~ P. 14/23 ~ ,",-. 'rjl ~" :"': t:...~~-,..: ~Y-04-200121 13:28 Sunday Sunday Sunday SundaY TR~~ TP. Appendix A - Example Month1Y Billing EJuimPl8 Month - April 2002 Volume Deliver8d (MWh)1 On-Peak Qff-PHk 01-Arlr-02 4800 1250 02-Arlr-02 4800 2400 03-A",-02 4800 2AOO 04-Am.02 4400 2/100 OS.ADr-o2 4BOO 2400 06-Aor-.800 1600 07-Anr-()2 NIA 7200 OS-Anr-Q2 04800 2400 Q9-A0P02 4800 2400 1 o-ADr0a2 4800 2400 11.Arlr-O2 4800 1700 12.AlIr..()2 3000 2400 130ADr-02 2400 2000 14-ADr0()2 NlA 3600 1S.ADr-02'4800 2400 16-ADr-02 4800 2400 17-4N002 ..800 2400 18-~4800 2400 19.Anr-Q2 .800 2400 2Q.ADr..Q2 4800 20400 21-ADr002 NfA 7200 22.ADr.(12 4800 2400 23-Anr.02 4800 2400 24-ADI'..Q2 4000 2000 25-ADr-02 4800 2400 26-ADr-D2 4800 2400, 27..ANoM oU3oo 2400 28.AnroO2 HI"7200 2i-Anr-02 4800 2400 ao-ADr.()2 . ,4BOO 2400 ActU8/ OJ MId.c Index Pric:e8 On-Peak OfI.p....k 26.42 14. 24.15. 28.14. 32.45 S 16. 27.40 S 15.21 22.32 S 13. NlA 18.23 28.86 14. 24.55 S 15. 28.76 S 15. 32.69 S 16.56 27 .84 S 15. 2:2.58 $13. NfA 18..47 24.12.11 22.21 13.20 26.12.77 30.35 S 14.22 25.90 S 13. 20.22 S 11.87 18. 28.96 111 2S.17.84 51.17.41 SUO 18. 29.94 17. 24.1821 NIA . S 20. 28.62 14. 24.15.50 To1aI 119400 84180 Total Volume DellverAd 2O358C MWh Mon1h1y BDI- Ch8rges to PaclflCorp Ch8lgos tor 1 &Otvf'N sold under COllared Index S1r\ICIUre . Charges fer 160MW 8OId unde, Rud Pric8 Structure S Total Monthly ail S 403 267 691116 16/23 " 0 .. .~ .. .. .... ' (Based on adUlll delivtny volumes) (Volume Welghtsd Average minus AdjUstment! (15OMW13OOMW . Tom! Volume DeIY8rwd) (150MWI3OOMW. Total VoIurTIII De/iv8I'8dJ 135,398.75 2,206.482.00 341.880:725 MAY-04-2001a 13: 29 TR~f=L TA.403 267 6986 The other reportable events listed in the table below are In no particular order. Although these events are reportable, they have no reducing impact on the Equivalent Availability Factor. Event Description of Other Reportable Events erve own - An event that exists whenever a unit Is avaUable for load but is' not synchronized due to lack of demand. This type of event is sometimes referred to as an economy outage or economy shutdown. If B unit is shut down due to any equipment-related problems, whether or not the unit was needed by the system, report an UnplaMed (Forced) Outage, Maintenance Outage, or Planned Outage, no a Reserve Shutdown. Nonc rtallina Event - An event that exists whenever equipment or major componentS are removed for maintenance, testing, or other purposes that does not result in a unit oute or deratin .0 No urtaffina Event - An event that exists whenever a unit is being intentionally . dispatched at a level less than its full capacity. when the designated capacity would otherwise be at full ca at because of lack of demand on the s em. - , 18/23 , ' L, " :....;'".,_ EI l a m p " Dr tll m d h r v sr u r n g . " " " q U 8 r 1 8 r l r "lI V e up - o f In c f 8 r c pr i c e d a r e r n r " , A I b t o p. a g ( ; ( J r p au a r t l l l l y Vo l u m e W~ t e d Aw 1 t 8 f J 8 fi t . Ba s i l DJ M k f . C Mc n h I y b l . FI a o c ' C8 I 1 i n g Dl l c o u n In c l C 8 I Ji l t - O C t $2 2 . $4 3 . S1 . 5 0 $3 2 . Fe b . o o $2 2 . 5 5 $4 . . 3 . $1 . 5 0 $5 0 . 0 0 Ma r - O S $2 2 . 5 5 $4 3 ; 8 0 $1 . 5 0 $2 3 . lr i l l a l B u m 0 / M o n t h l y Qu a r t e r t y A w 1 8 g 1 $2 2 . 5 5 ~3 . 8 0 $\ . 5 0 $3 4 . Ad d i i o n a J N n w o n M l ! A : h b l l . - . Ap p e n d I x C .tr . I\) .. . . In l l i a t I\ ) ~1 1 I a I P a y m e n t a t M o n t h E n d pa y m e n t a t Vo h l n e Ca Y ' a , M o n l h (C l l l c u l l l t l o n M e t t I O d J Mo n l h E n d 15 0 15 0 15 0 15 0 In t e m l t D u e ( b u e d o n I i s u m e d P r i m e r a t e o f S. 5 " 1 o 8 I 1 d b ' i l s no r m d y b e l n o d u e 2 0 d 8 Y 8 a n e , m o n l h e n d ) , F t l l t w l t h C M J I Cl l f n g . $ 4 , 88 8 . 8 0 0 Dif f e r e n c e 1 0 I n f t l l l l F e b b U s $4 7 3 , 7 8 0 In t 8 1 8 ' 1 1 d u e Ml l r d l 2 O I h t o A p d l 2 O l t l . Ca l S . Co 1 T( e d Ii - C O I 4 ) . 24 h 1 8 $3 , 40 3 , 80 0 Co t 8 . Cd T(C o I 31 - 24 1 1 1 8 . $4 , . t 1 5 , O4 O Ca l I . Co l T ( C o I 2 ) " 2 4 h f l . $2 . 51 8 , 5 9 0 $1 0 , 33 5 . 4 2 0 Co ! 6 . Cc J I T( C a I 5- C o I 4 ) " 2 4 h r s $1 0 . 11 9 2 . 00 0 "1 1 1 1 8 u p ' 0 1 Q u a l t e t \ y f l o o r s l c e l l l n g i $3 5 8 , 58 0 Ja n u a r y I n t l m l l Fe b r u a r y I n t e m ! S2 . 5 6 8 Ne l M a r d i J n w I c e $ 2 , 87 5 . 72 8 Fll I I / I C l a l S e I t \ I I I I C I I I e a c h t I H I I I I h w I U h i b.e o t f t I I D o w la n s d a l l , I~ .. e n l e l a W l ' m o n t h . If n l o n l b l y w e r q e I I I b I I I I b u k di t c : o m d e a c e e l l a R O O t t I J ' cd U 1 I 1 y a l ' 8 l l l h c m l l l l l h l y p 8 Y I I I U I t f r u m P a c I I l C o q l t o T r a D I A l i a w i n .. I d j l l S \ e d CII I _I r d d l l b B f s 1 0 r d 1 e c t 6e f l o o r a t C I d I I n t . A I ' tI J , e M o f e e r : b qu u u r , d l o . - . l h I y 1 1 1 \ 1 wi l l - t u d e a "t n t ; 1 I 1 u p " : w h e R b y t i l l qu l n a \ J a v e r D I . o r th e D A I l y D o w J a n e s " u l e x p r i c e s 1I I I D u a b. . I , di . _ r wil l b e C I I I 8 p G I I I ' 0 O l e f t o a r .. . .. . . YI I D c 8 . T o t b a r s t l l n l D I I C I f I I I d cd 1 I l I l l d j l l l l n l l l l l l l 8 1 l i . a D U I n i l i d bu l l - no t r a t I J l r e d w h e n v i e w e d o n I q a a r t r . r l y b a s i s . cn d l l o r p a y m l : l l t w l l J CI C C I l ' a D th a t a t l i o n t h ! r b R I o r a d ! c p d e r . P l J l n a l l O I md U f l l l ' h I a I d 1I I I t 0 0 I a l M l l w l U '- . " - . . , dm e o r - l l I I O I 1 l h \ y p l Y r n : D I J _ 1 4 _d l l O l 1 l 1 l 1 1 d i e qu u t e l l y p a y a n e n l w I l l b e d u e . /8 ; .t r . (J ' I MAY-04-200111 13: 30 TR~~ TA 403 267 6906 Confinnation Agreement 22/23 , '~ ,. "..., -,.. .:.. OUTLOOK POINT OF DELIVERY Location: the point in PacifiCorp s Outlook Substation where the 230 kV facilities of the Parties hereto are connected; Voltage: 230 tV; Metering: in PacifiCorp s Outlook'Substation, in the 115 kV circuit over which electric power and energy flows; Exception: there shall be an adjustment for losses between the point of m~riDg and the point of delivery; PILOT BU'ITE POINT OF DEUVERY Location: the point in BPA's Rcdmond-Yamsay 230 kV tranSmission line where the facilities of the Parties hereto arc connected; Voltqe: 230 tV; Metering: In PacifiCorp's Pilot Butte Substation, in the 69 tV circuit over which elecuic power and energy flows; Exception: there shall be an adjustment for losses betWeen the point of metering and the point of delivery, PONDEROSA POINT OF DELIVERY Location: th~ point in BPA's Pondcrosa Substation whe~. the 230 kV facilities of the Parties. hereto iriconriected; .. ",. " '~ -" .' ' t ' . '. ' ~'I. .... Voltage: 230 kV; Metering: hi BP A 's Ponderosa Substation, in the 230 kV circuit over which electric power BOd energy flows; RESTON POINT OF DELIVERY Location: the point in BPA's Reston Switching Station where the 230 kV facilities of the Parties hereto arc connected; Voltage: 230kV; Metering: in BP A 's Reston Switching Station, in the 230 kV circuit over which electric power and energy flows; LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Appendix A Appendix B Appendix C Appendix D Appendix E Appendix F Annual Variable Cost A-1 Resource Pool . B-1 Service Schedule D to the TEP Interconnection Agreement C-1 Service Schedule E to the TEP Interconnection Agreement . D-1 Power Exchange Examples . E-1 Example Calculation Establishing Adj ustments for Interest . F-1 Redding II II (Original Agreement II ) which provided for PacifiCorp to sell 50 megawatts of capacity and associated energy to Redding for twenty years from June 1, 1994 through May 31, 2014, subject to certain termination rights. Insofar as a portion of the capacity and associated energy that would be purchased by Redding would be in excess of Redding's needs, with such portion declining over t:.me. Redding entered into a II Contract for Purchase of Power and Provision of Services II with the United States of America, Department of Energy, Western Area Power Administration ("Western") pursuant to which Western would purchase the portion of capacity and associated energy which Redding purchased from PacifiCorp and which was in excess of Redding's needs.The term of Redding' agreement with Western is coterminous with the term of the Original Agreement, subj ect to certain termination rights. Redding is a member of the M-S-R Public Power Agency ("M-S-R"), a joint powers agency duly organized under the laws of the State of California and consisting of the Modesto Irrigation District. the City of Santa Clara~ and the City of Redding. M-S-R is a party to an agreement with the Bonneville Power Administration ("BPA") dated October 31, 1989, under which, among other things, M-S-R currently purchases 100 megawatts of capacity and associated energy from BPA. has a 15\ interest in this agreement. Redding Page 2 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Because of seasonal diversity in their loads, Redding and PacifiCorp would benefit from a new contractual arrangement that would provide for a seasonal exchange of capacity and energy while accommodating existing contractual arrangements. Aqreement The Parties agree to the terms and conditions set forth herein. Definitions As used herein, the following terms have the following meanings when used with initial capitalization, whether singular or plural: Additional Energy" means the sum of available Winter Energy and available Short Fall Energy, both of which are defined below. Agreement" means this Agreement between Redding and PacifiCorp, including Appendices A, B, C, D, E and F, which are attached hereto and made part of this Agreement. Annual Variable Cost" means, in any calendar year, the weighted variable cost expressed in dollars per megawatt- hour ($/MWh), as determined by the methodology set forth in Appendix A, of the resources contained in the Resource Pool in such calendar year, with such costs of new resources, if any, Page 4 -LONG - TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Firm Energy" means the energy associated with Firm Capacity. Maximum Entitlement" means Redding's 4.32 percent enti tlement (15 percent of M-S-R I S 28.8 percent entitlement) to San Juan Unit 4 energy production. Northwest A.C. Intertie" means the 500- transmission facilities or portion of transmission facilities in Oregon as described in the Northwest Intertie Agreements, such agreements being the agreements between and among BPA, PacifiCorp, and Portland General Electric (Northwest Participants) and any amendments thereto, which among other things, set forth the Northwest Participants I rights and obligations between and among themselves with respect to the Northwest A. C. Intertie and associated facilities, identified as the BPA-PacifiCorp Contract No. DE-MS79-94332 and associated agreements and the BPA-Portland General Electric Contract No. DE-MS79-87BP92340 and associated agreements. Off-Peak Hours" means the hour ending 2300 through the hour ending 0600 Pacific Time, Monday through Saturday, all hours on Sunday, and the holidays of New Year I s Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day. Point of Delivery" means, for all deliveries of Firm Capacity and associated Firm Energy from PacifiCorp to Redding, points on PacifiCorp I s system as mutually agreed upon Page 6 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Short-Fall Energy" means amounts by which Redding schedules Seasonal Energy below 20 megawatt-hours in any hour as provided for in Sections 9.4(a) and 10. "Winter Energy" means energy available to Redding equal to the amount of energy from San Juan that PacifiCorp schedules in excess of 12, 000 megawatt-hours in any month of a Contract Year. Term and Termination Effective Date and Termination Date This Agreement shall be effective following its execution by both Parties and upon its acceptance for filing, as provided in Section 5. Service shall commence at the hour ending 0100 on the first day of the month following acceptance for filing by the Federal Energy Regulatory Commission ("FERC" ( " Service Commencement Date") which the Parties anticipate will occur on or before February 29, 1996.Except as provided in the termination options set forth in Sections 5.2 and 16, and except as to allow for the delivery of Exchange Energy to Redding (if any) pursuant to Section 9.6 through 2016, this Agreement shall terminate at 2400 hours, November 30, 2015. Reaulatorv ~ccroval PacifiCorp shall file this Agreement with the FERC in a timely manner subsequent to its execution.PacifiCorp shall provide Redding with a copy of the filing prior to submittal to the FERC and Redding shall file Page 8 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Maxi mum Amount of Reduction December 1, 1995 through May 31, 1996June 1 , 1996 through May 31, 1997June 1, 1997 through May 31, 1998June 1, 1998 through May 31, 1999June 1, 1999 through May 31, 2000June 1, 2000 through November 30, 2000 35 MW 30 MW 25 MW 15 MW 5 MW 0 MW The Firm Energy delivery provisions pursuant to Section 7 shall apply to the reduced level of Firm Capacity.Redding may elect such reduction by giving PacifiCorp 30 days advance written notice prior to the effective date of the reduction and the reduction shall continue for not less than 12 consecutive months.Any reduction in Firm Capacity and associated Firm Energy shall be considered "Undelivered Power" and shall result in the adjustment set forth in Section 8. Firm Enerav Deli verv Provisions Beginning on the Service Commencement Date and continuing through November 30, 2000, PacifiCorp shall deliver Firm Energy associated with Firm Capacity at load factors, as scheduled by Redding, not to exceed 100 percent per hour, 100 percent per month, and 85 percent per Contract Year.Redding shall purchase such Firm Energy at load factors of not less than 70 percent per month, and 85 percent per partial Contract Year or full Contract Year. Page 10 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING billi~g purposes in the remaining billing periods for such Contract Year. for Firm Energy on a Contract Year basis that differ from To the extent such estimates result in payments Redding I s obligation to pay as stated in Section 8.2, the Parties shall reconcile such differences pursuant to Section 11. Undelivered Power Adiustment In the event of be as follows: Undelivered Power, Redding I s continuing obligation to pay shall Redding shall pay the price set forth Section 8.1 for 50 megawatts of Firm Capacity. month for Undelivered Power as set forth below: Redding shall pay or receive a credit each Monthly Adjustment (in ($) = R x(M - EAVC)/2, where: EAVC= c x 730 hours x LF, where R =Reduction Firm Capacity (MW) and LF = energy load factor during such month Index of the arithmetic average of the weekly spot electricity prices during such month at the California-Oregon border as published in McGraw-Hill' 5 "Power MarketsWeek" .(Example: Index for week endingNovember 17, 1995=$14. OO/MWh. SeePower Markets Week publication dated November 20, 1995). the Estimated Annual Variable Cost ($/MWh) specified in Section 8. If the adjustment is a negative number, such amount shall be added to Redding I s bill for such month.Conversely, if the Page 12 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING combination of Redding I s Maximum Entitlement to Unit 4 Power and Redding I s rights under Appendix D to this Agreement, provided that, if Redding's rights to San Juan Power are reduced during San Juan unit outages, PacifiCorp I s rights to Power under this Agreement shall be reduced to the amount available to Redding under Appendix D to this Agreement. 1.2 Reddina I S Riahts to San Juan Power the extent, in any given hour, PacifiCorp does not exercise its full rights under Section 9.1 of this Agreement, together with associated transmission delivery rights, Redding shall have the right to schedule for its own account capacity (and associated energy) equal to the difference between the maximum amount of San Juan Power made available pursuant to Section 2 . 1 . 1 in a given hour and the amount of San Juan Power that is being scheduled by PacifiCorp for that hour; provided however, Redding I s rights shall at all times be subordinate to PacifiCorp I S prescheduling and real-time scheduling rights from San Juan. 1.3 Minimum Deliverv Obliaations During each hour during which San Juan Unit 4 is operating, PacifiCorp shall have the obligation to take delivery of a minimum of the lesser of Redding I s share of the San Juan minimum hourly output or 9 megawatt-hours per hour.During times when Unit 4 is unavailable, this obligation shall become zero.During each Contract Year, PacifiCorp shall have the obligation to take Page 14 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Minimum Hourly and Monthly Deliveries Redding shall have no obligation to take delivery of Power in any hour but shall have the obligation to take delivery of at least 16,250 megawatt-hours in each month. Maximum Hourly and Monthly Deliveries Redding shall have the right to take delivery of 50 megawatt- hours in each hour and 27 500 megawatt-hours in each month. Maximum Seasonal Deliveries During each Season, Redding shall have the right to take delivery of an amount of Seasonal Energy. the following circumstance: Such amount shall be reduced in If, for any hour during a Season, Redding schedules less than 20 megawatt -hours, the amount of the short-fall below 20 megawatt-hours ("Short-Fall Energy"), shall accrue as Additional Energy pursuant to Section 6); provided, however, for such hour, 20 megawatt- hours shall be subtracted from Seasonal Energy and the annual minimum delivery obligation pursuant to Section Chanaes in San Juan Enerav Availabili tv If San Juan Unit 4 is permanently rerated such that the hourly energy available pursuant to the Maximum Entitlement is more or less than 21.5 megawatt-hours, the numerical limits set forth in Sections 9.2 and 9.4 and the number "27,500" in Section 9.3 shall be correspondingly Page 16 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING (ii) on a nonfirm basis during the months of December, January and Feb~uary during hours as mutuall y agreed by the Parties; or (b)Subject to the provisions of Section 10. Redding may take delivery of 75 percent of any accumulated Additional Energy on a firm basis during Off -Peak Hours during the months of December through April and November, with the corresponding 25 percent of accumulated Additional Energy being forfeited. Prior to November 1 of each Contract Year during the Exchange Period, Redding shall provide PacifiCorp with written notice of which of the aforementioned Additional Energy delivery options it has selected for the ensuing Contract Year. Exchanae Conversion Oction If, during any consecutive 24-month period, energy from San Juan is not available to PacifiCorp for a cumulative total of 4,380 hours, for any reason, upon providing Redding with 60 days advanced written notice, PacifiCorp may elect to convert the delivery of San Juan Power to San Juan Alternate Power.Within such 60 day notice period, Redding may elect to procure San Juan Alternate Power from a third party; provided, however, that PacifiCorp shall have right-of-first-refusal to provide such San Juan Alternate Power at the purchase price quoted to Redding for such San Juan Alternate Power.I f Redding does not procure San Juan Alternate Power, PacifiCorp shall be obligated to provide Page 18 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING subsequent peak load (s) .In no event shall PacifiCorp be liable to any party in connection with any impairment or loss of the tax-exempt status of bonds issued by M-S-R in connection , with San Juan, and Redding shall indemnify and hold PacifiCorp harmless in regard to any claim associated with any such impairment or loss. 10.Schedulina 10.Preschedules of Enerav bv Reddina Redding shall preschedule (by telephone unless otherwise agreed by the Parties I schedulers) deliveries of Firm Energy, Exchange Energy and Additional Energy from PacifiCorp no later than 1000 hours Pacific Time on each work day observed by both Parties immediately preceding the day or days on which such energy is to be delivered, or as mutually agreed by the Parties dispatchers or schedulers.PacifiCorp shall deliver in accordance with those preschedules which comply with the delivery obligations specified in Sections 7 , 9 and 10. the event of changes in Redding I s system between the time of preschedule and the actual schedule hour, due to significant changes in resources and/or loads, Redding may request a change in preschedule with no less than a two and one-half hour notice prior to the hour of delivery, and PacifiCorp shall make best efforts to accommodate such changes in Redding 's preschedules. Page 20 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING If Redding has elected the Additional Energy delivery option set forth in Section 9.7 (b), the Maximum Hourly Rate of Delivery (stated in megawatt-hours and rounded to the nearest megawatt-hour) shall equal the result of the following equation: 5 x M = Maximum Hourly Rate of310 Off-Peak Hours per month Delivery (megawatt-hours) Where:Maximum Monthly Rate of Delivery calculated above Provided, however the Maximum Hourly Rate of Delivery of Additional Energy shall in no event be less than 5 megawact- hours per hour nor greater than 50 megawatts per hour. 10.No Car~Y Forward Redding shall not be obligated to schedule any minimum amount of Additional Energy. Except provided for in Section 9.6, any amounts accumulated prior to the Season of the current Contract Year and not scheduled during such Contract Year shall not be carried forward to any future Contract Year. 10.Schedulinq of San Juan Enerqy by PacifiCoro November 10 of each Contract Year during the Exchange Period, PacifiCorp shall furnish Redding with a nonbinding estimate showing PacifiCorp I s anticipated monthly schedule of San Juan energy for the following Contract Year.By the 23rd day of each month, PacifiCorp shall furnish Redding with a nonbinding estimate for the following month of expected hourly deliveries of San Juan energy.Such estimate may be in the form of a Page 22 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING 10.Schedule Curtailments 10.Curtailments of Deliveries At times when PacifiCorp is unable to deliver or Redding is unable to receive deliveries of energy hereunder as a result of the Western Area Power Administration I s inability to receive deliveries of energy from Redding due to curtailments by Pacific Gas and Electric Company (PG&E) for low load conditions in the PG&E service area, or a curtailment of schedules on the Pacific Northwest/Pacific Southwest A. C. Intertie due to loop flow or line outages, Redding shall be relieved of its obligation to accept such energy and PacifiCorp shall be relieved of its ob~igation to provide energy during those hours of curtailment conditions.The Parties shall use best efforts to estimate the hours of such curtailments and submit such estimates in a timely fashion.Any energy interrupted hereunder shall be rescheduled in amounts and at times as mutually agreed by the Parties' schedulers and dispatchers. 10.Precedence of M-S-R Resources The Parties agree that if transmission schedules on the Pacific Northwest/Pacific Southwest A. C. Intertie are curtailed, Redding's M-S-R/BPA resource shall take precedent.That is, if transmission curtailments are required, Redding's share of such curtailments shall be met first by reducing its deliveries under this Agreement; provided, however, with respect to curtailments, that deliveries under this Agreement shall take Page 24 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING 11.2 Annual Adiustments Prior to the September of each of the calendar years 1997 through 2001, utilizing the FERC Form 1 data upon which the Annual Variable Cost is based, PacifiCorp shall determine Redding's payment obligation for the Contract Year ending November 30, nine months prior to such September based on the prices determined in accordance with Section 8.2 and applied to Firm Energy pursuant to Section In the event the amount so determined is greater than the amount actually paid by Redding pursuant to Section 11. PacifiCorp shall add the amount of such difference, as adjusted for interest pursuant to Appendix F, to the September invoice of said year.In the event the amount so determined is less than the amount actually paid by Redding pursuant to Section 11.1, PacifiCorp shall subtract the amount of such difference, as adj usted for interest pursuant to Appendix F, from the September invoice of said year; provided, that, if such amount to be subtracted is greater than the September invoice amount, PacifiCorp shall promptly pay to Redding the difference between such amount and the September invoice amount.However, if the difference is greater than ten percent of the total annual payment obligation associated with the Contract Year being adjusted for, then either party may elect to spread the payment associated with such difference over a twelve month period commencing with the September invoice of said year with Page 26 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING 12.Cost Determination Chanqes The cost methodologies utilized for pricing purposes in this Agreement and the pricing formulae specified herein shall remain in effect through the term of this Agreement, and neither Party shall petition the FERC pursuant to the provisions of section 205 or 206 of the Federal Power Act to amend such methodologies or formulae, or support such a petition by any other person or entity, absent agreement in wri ting from the other Party. 13.Audi t Riqhts 13.Reddinq 's Audit Riqhts Redding, at its expense, shall have the right to audit and to examine any cost, payment, settlement or supporting documentation related to any item set forth in this Agreement.Any such audit shall be undertaken by Redding or its representatives at reasonable times and in conformance with generally accepted auditing standards.The right to audit a cost shall extend for a period of five years following the billing for such cost under this Agreement. PacifiCorp fully agrees to cooperate with such audit and to retain all necessary records or documentation for the entire length of the audit period.Redding shall take all steps reasonably available to secure the confidentiality of PacifiCorp I S accounting records and supporting documents. Page 28 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING To Redding: Electric Utility Director Ci ty of Redding 760 Parkview Avenue Redding, California 96001-3396 with a copy to: City Manager Ci ty of Redding 760 parkview Avenue Redding, California 96001-3396 To PacifiCorp: Vice President, Power Systems and DevelopmentPacifiCorp 825 NE Multnomah, Suite 485Portland, Oregon 97232-4116 wi th a copy to: Manager Customer Contract AdministrationPacifiCorp 825 NE Multnomah, Suite 625Portland, Oregon 97232-4116 The Parties may change at any time the persons to whom notices are addressed, or their addresses, by providing notice thereof as specified in this Section 14. 15.Uncontrollable Forces Neither Party to this Agreement shall be considered to be in default in performance of any obligation hereunder if failure of performance shall be due to an Uncontrollable Force. The term "Uncontrollable Force II means any cause beyond the control of the Party affected, including, but not limited to, failure of facilities, flood, tsunami, earthquake, storm, fire, Page 30 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING lightning, epidemic, war, riot, civil disturbance, labor disturbance, sabotage, and restraint by court order or public authority, which by exercise of due foresight such Party could not reasonably have been expected to avoid, and to the extent that by exercise of due diligence it shall not have been able to overcome.A Party shall not, however, be relieved of liability for failure of performance to the extent such failure is due to causes arising out of its own negligeace or to the extent such failure is the result of removable or remediable causes which it fails to remove or remedy with reasonable dispatch.Any Party rendered unable to fulfill any obligation by reason of an Uncontrollable Force shall exercise due diligence to remove such inability with all reasonable dispatch and shall notify the other Party of such Uncontrollable Force as soon as practicable.Nothing contained herein, however, shall be construed to require a Party to prevent or settle a strike against its will. 16.Requlatorv ImDact In the event that the FERC or any agency or court of competent jurisdiction materially modifies any term or condition of this Agreement in such a manner that either Party is required to incur new or different obligations not expressly provided herein, the Parties shall attempt in good faith to renegotiate the terms and conditions of this Agreement so as to Page 31 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING harmless the First Party from , such liability.As used in this Section,(1) the term "Party" means, in addition to such Party itself, its directors, City Council members, officers, and employees;(2) the term "damage" means all damage, including consequential damage; and (3) the term "person II means any person, including those not connected with either Party to this Agreement. 19.DisDute Resolution The Parties shall make best efforts to settle all disputes arising under this Agreement as a matter of normal business and without recourse to litigation.Pending resolution of a disputed matter, the Parties shall continue performance of their respective obligations pursuant to this Agreement. 20.Amendmen t S This Agreement may be amended only by a written document signed by both Parties hereto. 21.Assianabili tv This Agreement shall not be assigned without the prior written consent of the Parties, which consent shall not be unreasonably withheld, Drovided , however, that this Agreement may be assigned without prior consent to the following: Page 33 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING IN WITNESS WHEREOF, the Parties hereto ~ave caused this ~greement :~ be executed in their respective names by their respective officers thereunder duly authorized. (SEAL) Title: Assistant Address:760 Parkview Avenue Reddin 96001 B . \..1. I VlkL)..( ."\./. ., ...; By: Title: Address:700 N.E. Multnomah, Suite 1600 Portland, OR 97232 Page 25 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING Section A2:Determination of Colstri Pro ect Annua Variable Cost.Jim Brid er Pro ect Annual Variable Cost.Hunter Pro ect Annual Variable Cost Hunter Pro t Annual Variable ost The Colstrip Project Annual Variable Cost, the Jim Bridger proj ect Annual Variable Cost. the Hunter #2 Proj ect Annual Variable Cost and the Hunter #3 proj ect Annual Variable Cost shall be determined, for each Project. by (a) adding the amounts as set forth in Sections A2.1 through A2. (plus A2. 3 for Hunter #2 and plus A2.4 for Hunter #3) and (b) dividing each Project total by PacifiCorp's share of the associated Project's annual energy production as filed with the Federal Energy Regulatory Commission (FERC) in Pac if iCorp I s FERC Form No.1, or its successor thereto. A2.Production Expenses shall be equal to the production expenses of resources in the Resource Pool "as filed in PacifiCorp's FERC Form No.1. or its successor thereto. A2.In lieu of payments shall consist of any assessment. payment in lieu of taxes or other charge which is imposed against ?acifiCorp by governmental authority and related to the operation and maintenance of each proj ect. A2.Hun~er #2 Project allocated m~n~ng expenses, to be determined by adding the amounts calculated under Sections A2. 3. through A2. 3 . 4 below: A2.PacifiCorp's adjusted initial levelized annual fixed charge rate for the Hunter #2 proj ect mining investment multiplied by the Hunter #2 project mining initial investment, Appendix A - 2 amount equal to t~e produc~ of 1) the quotient of to~al PacifiCorp a~~inistra~~ve and general expenses to total PacifiCorp electric plant in service; and 2) the total Hunter #2 proj ect mining inves tmen t A2.Hunter #3 proj ect allocated mining expenses. to be determined by adding the amounts calculated under Section A2. 4. through A2. 4.4 below: A2.PacifiCorp's adjusted initial levelized annual fixed charge rate for the Hunter #3 Project mining investment multiplied by the Hunter #3 Project mining initial investment, determined pursuant to Section A3, as of December 31, 1990.For purposes of this section. PacifiCorp I s total investment in Hunter #3 project ~ining is $44,588,747.Such total investment shall remain constant through the book life (14 years) and shall be $0 afterwards.Such adjusted initial levelized annual fixed charge rate shall be determined by subtracting book depreciation (l/book life) from PacifiCorp I s initial levelized annual fixed charge rate for the Hunter #3 proj ect mining investment determined annually in accordance with Section A4. below. Such book depreciation is reflected in Hunter #3 fuel cost. A2.Each subsequent annual levelized fixed charge shall be determined by multiplying (a) PacifiCorp' s subsequent levelized annual fixed charge rate for the Hunter #3 Project mining investment. as calculated in accordance with Section A4, below, by (b) the dollar investment in capital additions, replacements (less credit for net salvage and insurance proceeds, Appendix A - 4 :~e rat~o of Pac~:~Corp' s share of the associated Projects capab~li:y (23 5 !~n fc= H~n~e= #2 Proj ect and 400 MW for Hunter #3 ?=oject) divided ~1 :te :~:a~ ca;ab~:i:1 cf a:: ?=~je~~s served by the mines (presen~ly 1995 MW) . Gross coal plant, as reported in FERC account 399 as Total Other Tangible Property" in PacifiCorp' s FERC Form 1 as of December 31, 1990. Each subsequent coal mine investment in capital additions, replacements (less credit for net salvage and insurance proceeds, if any), and betterments, as determined pursuant to data contain in PacifiCorp's FERC Form 1 or its successor thereto. Section A4:Elements of Hunter #2 and Hunter Pro; ec inina estment Levelized Annual Fixed Charae Rates A4.CaDital ctur A4 . 1. 1 For purposes of calculating initial levelized annual f~xed charge rates. PacifiCorp I s capital structure will rema~n constant.~he capital structure for Hunter #2 and Hunter #3 Project is: Long Term Debt Preferred Stock 50% 10% Common Stock Equity .4Q% ':'otal 100% A4 . 1 . 2 PacifiCorp I S capital structure will remain constant for purposes of calculating subsequent levelized annual Appendix A - 6 levelized annual fixed charge ra~e is calcula~ed.In the event there are ~o bond issues wi~hin the said twelve (12) -mon~h period, then an es~i~ated =~nd interes~ ra~e will be used i~ r.~e =il~ings. based upon the bond =ating then applicable to PacifiCorp until such time as there is a bond issue, at which time all future billings will reflec~ the actual cost to PacifiCorp of such bond ~ssue .In the even~ such bond issue is subsequently exchanged for other bonds, the new bond rate shall be used for subsequent billings. A4 . :2 . Preferred Stock Return on preferred stock applicable in the calculation of each initial levelized annual fixed charge rate shall be eight and twenty-four hundredths (8.24%) .Return on preferred stock applicable in the calculation of subsequent levelized annual fixed charge rates for future capital additions, replacements, or betterments shall be the same as for bond interest used in calculation of subsequent annual fixed charge rate. plus fifty (50) basis points. A4 . :2 Common Stock Eauitv For pricing purposes only the component for the rate of ROE applicable in the calculation of the initial levelized annual fixed charge rate and each subsequent levelized annual fixed charge rate for any calendar year shall be equal to PacifiCorp' s then-effective rate of ROE which has been authorized by the FERC. PacifiCorp shall use a rate of ROE of eleven and seven~y-hundredths percent (11.70%) as authorized for use by FERC in FERC :)ocket No. ER-93-052-000. PacifiCorp shall make a timely Appendix A - 8 whic~ Pac::iCorp provides retail serv1ce. A4 . 4 . 3 ~he Modified Accelerated Cost Recovery System (modified ACRS) method of tax depreciation in accordance with the ~ax reform act of :986 shall be used in calculating both the initial and subsequent levelized annual fixed charge rates. A4 Regular Investment Tax Credits allowed in accordance with the provisions of the Internal Revenue Code of 1954, as amended, regardless of whether PacifiCorp is able to use such credits shall be used when calculating subsequent levelized annual fixed charge rates. A4 4 . 5 ~ax basis shall be one hundred percent (100%) of the book basis in calculating each initial levelized annual fixed charge rate and one hundred percent (100%) of the book basis in calculating each subsequent levelized annual fixed charge rate. Appendix A - 10 Jim Bridger Proj ect Annual Variable Cost (Based on 1990 FERC Form P~oduct:on Excenses Operation, Supervision and Engineering Fuel $ 1, 906,989 110,073,590 Steam Expense 378,692 924,875Electric Expense Misc. Steam Power Expenses Rents 996,408 36,080 Maintenance. Supervision and Engineering 402,476 296,637Maintenance of Structures Maintenance of Boiler Plant 12,060,367 361,026Mai~tenance of Electric Plant Maintenance of Misc. Steam Plant 458,585 --------- Sub-Total $143,895,725 :~ Lieu 0: Payments ~otal Variable Costs Jim Bridger Project $143,895,725 727,673Annual E~ergy Production (MWh) Jim Bridger Annual Variable Cost $14.79 /MWh ------------------ Appendix A - 12 Hunter #3 Proj ect Annual Variable Cost (Based o~ 1990 FERC Form Production Exoenses Operation. Supervision and Engineering Fuel Steam Expenses Electric Expense Misc. Steam Power Expenses Rents Maintenance. Supervision and Engineering Maintenance of Structures Maintenance of Boiler Plant Maintenance of Electric Plant Maintenance of Misc. Stearn Plant Sub-Total Allocated !'!ining Expenses ... :n Lieu of Payments Total Variable Costs Hunter #3 Project Annual Energy Production (MWh) Hunter #3 Project Annual Variable Cost * See Attached sheet A-18 for details Appendix A - 14 562,579 26,295,191 281,882 1. 277 460 1, 199,505 254 855,461 575,125 026,339 243 , 417 111,556 --------- $35,429,769 $3.745,023 $39.174,792 348,751 $11. 70 IMWh ------------------ HUNTER # 2 AND # 3 M~N~NG ~NVESTMENT ALLOCAT~ON CALCULAT~ON Gross Coal Plant (=E~C F .l-?g 207a)$222,386,377 Power Plants served by Mines:~OJ Huntington # Huntington #2 Hunter #1 UPLHunter # 1 Provo Hunter #2 UPL Hunter #2 DG&T Hunter #3 UPL 400 415 366 235 155 400 Total:1995 Hunter #2 Mining Investment = 235/1995 x $222,386,377 = $26,195,889 Hunter #3 Mining Investment = 400/1995 x $222,386,377 = $44,588,747 Appendix A - 16 HUNTER #3 PROJECT ALLOCATEDMINING EXPENSE CALCULATION (Based on 1990 Actual Cos ts ) Initial Levelized ~~nual Fixed Charcre Hunter #3 Pro;ect Hunter #3 Mining Investment* Adjusted Initial Levelized Annual Fixed Rate Ini tial Levelized Annual Fixed Charge Subsequent Investment Subsequent Levelized Annual Fixed Rate Subsequent Levelized Annual Fixed Charge Ad Valorem Tax Taxes, assessments and in lieu of taxes Administration & General Expenses: $44,588,747 551% $2,921,009 :990 ~otal PacifiCorp A & G Expense = $145,713,190 1990 Total PacifiCorp Electric Plant In Service = $7,884,778,137 A & G Expense as a percent of Investment = 1.85% Hunter #3 A & G Expense = 5824.014 Total * See attached sheet A-16 for details. Appendix A - 18 $3,745,023 HUNTER #2 AND #3 MI:NE INVESTMENTFORMULAS FOR CALCULATINGINITIAL LEVELIZED FI:XED CHARGE RATE (Sample Calculatio~s based on Year 1 and shown rounded to nearestwhole dollar) 1) CAPITAL RECOVERY FACTOR, (CRF) = i(l+i)n/ (l+i)n -1Where i weighted cost of capital and n = ave.life of plant. CRF = 0.0974(1 + 0.0974) 14/((113382 0974) 14 - 1) 2) BOOK DEPRECIATION = 5100,000/14 Years 57,143 3) TOTAL RETURN.(TR) Where A = A x Ws = Average Net Investment; and = Weighted Cost of Preferred and Common StockLet A = Beginning Investment - (D+T) /2~fuere Beginning Investment = Previous year I s beginninginvestment - previous year I s D and T. = Book Depreciation (*2)= Deferred Tax (*Therefore. beginning investment = 5100,000 = 5100,000 - (7,143 + 2631) /2 =$95,113TR = $95,113 x (.10 x .0824 + .40 x1170) = $5,235( * 4) INTEREST, ( I) A X Wd~fuere Wd = Weighted Cost of Debt Therefore. I = $95,113 x (.50 x .0847) = 54,028 5) DEFERRED TAX. (T) Where To TR Let T = (To -D) x TR Tax Depreciation (*8) Tax Rate (36.81%) (14,290 - 7 143) x .3681 =$2,631 Appendix A - 2 APPENDIX B RESOURCE POOL This Appendix sets forth the amount of capacity (MW) and the combination of resources which may be included in the Resource Pool which shall be the basis for determining the prices for Firm Energy under Section 8. During the period June 1, 1996 through November 30, 2000, the Resource Pool shall contain 800 megawatts of capacity consisting of the following combination of resources: Resource Capaci ty .llikil. 235 Colstrip Project Jim Bridger Project Hunter No.2 proj ect Hunter No.3 proj ect Total ll!l 800 MW Provided , that commencing June 1, 2000, and continuing through the the Contract Year ending November 30, 2000, PacifiCorp may replace up to a maximum of 100 megawatts of resources and associated costs i~ the then-existing Resource Pool with other cost resources; i. e.. in the Contract Year ending November 30, 2000 the Resource Pool shall contain a minimum of 700 megawatts of resources that were included in the Resource Pool in the Contract Year ending November 30, 1996. Appendix B :JO. ~ =0. =0. DO. ""'" -"'. - APPENDIX C ,.--- --"'.".-----.... . -- --.. (-....--' . .:...:. --.'."':"- - --..'1 .1"\""....':":"... ':'., . betwe~~7::C:=~: ~:'=:7~!C: :;::OW~:.. C::~wi?A.N" a.na M. ?. ?U= .:..:= POWE:.. ACZNC- P..EVI~:J S:E:? V:C~ SC~E~U!.~ D ?OW~? E~=HA NCE AC?:E:~MEN7 orais Ser'"'"1ce Sc~edule D is agreed upon as par: of the L::.:erc=::.::.ec=::. . .:. . gr eec-.ent entered i:.:o between 7::C:ON ::::..:E:=-=~= POW::::. C=:~_NY ("1"Fscc'l And M -A ?UBUC: -- -~'-" ", ~ '".. ~:.. .~~...'C ~ ..Vi.- -~ :u: L.S Tucson CW'US an o;r..:.o:. to a.::~::i:e a..c. u=.c!.i..-iaec z::. g percent i..:.:erest :..=. :'::e Sa.n Jua.n Gener:1ti:g S:a.ticn U:i: No. -% (It s.: J~ 4" and ?la..ns =0 c::.:::.:: :: sell sa.ie optio:. :0 M -5- A. M - S -?. i::.:e r-.c!. s toe xe c:. settle 0 pti:::. a..c.d be come a.a Cwft.e r as a teaa.::.: :.: =::-"_-::.o=. 0: Sa.n Juan 4- e!!ective on Ma.y 1 1995. R desires to receive t:.e energy ou:;:ut fro: its owner- snip i:.terest i:. Sa..n Jua..n 4- at t~e ?a.lo Verde Nuciea.r Geoeruing Sta.tion Swit::ya.rd ("::'V'NCS:S", , the Moenkopi Substa.:c:..0: the We stW'ing SVl'it::::~..a.rci. Tucson ha.'! owne::::i~i::.:er st : -"" 5 i" ?V~:GSS. tne .. ..~.... :V~oenkcoi .5;.:os:a.:i:::.. and t::'e We scoRing Swi:=:-.~..a.r.:.'I -,-.., ,:a ~..., ~~~-;; -':~. .~, '., ...../- - ., " (7 -Appendix C - D3. D:3. !J4. ,... "~y :':'".~:~3.1 ;lg:e~::-.e::.: :::.i :~e ~3.::~es.:-:-.is . .:.. g :e~::-'e::.: ~ s binding ~?on :~e ?J.::ie S :':;::0:1 :~e exec~:ion ~e reeL 5EC-=:ON D3 EXCH.o\NGE Dur:.::.g the ter::-. hereei. ~.t-R sha.ll deliver to !'l.1csCln its entitleme::.: :0 genera.tion at the 5a.n Jua.n Cic:n~r3.t:.:.g Station. HClur by hour. :-l.1cso~. will deliver or will a.rr:Lnge le:' :::.e provision :0 M-R of a like a::-.cu::.: of C:L?a.c:.:y and the aelivery 0: a like ..mou::.: 0: as soCi3.tec ene rgy at PVNGSS. the Moenjcopi. Subs:a.:iCln. or ::e WestWing Switc:yard. There snoul:i be ::'0 i=bala.nce i::. energy celiveries.!.a the eVent ::.u suc:. :-!-' ~ces sheuld eccu: due to sc:.eauLeci or :'o::.sc~duled outages. ~e Opera.c.:g Ccr!'!--:-..i ::ee :eprese.c.ta.:i.ves Rill .J.:::u:.ge fo: sc:.edules and delivery :':Ltes to co:rec: ::-.e icoa.lance. 5!:C-=:ON D4 5CHEDULL.'lG Dur:.::.g the period of t:e Agreement. i\. shul schedule energy deliveries to 'I'l.1cson by previdi.:1g !'l.1cson by the t'Wency- !~::. (25::) ca.)" ot ea.c::. ce::.:::. a writ:e.c. eStica.te 01 ::e aail)" C:lec We s %.or :::.e to .0W'l.::.g mont_.1."1 addition. ~t-R will CV1 - - "'.:.. C::~ ""'; a.r .J - ... . 1.1 :_" :"" ":-" .... . w'. ... -.. _.. ...,. ~ ~. me ea.c.. c . C ..oo!! .. :er:::. ~ereoi an esti::-':L:e oi the iollowing ciay s hour-by-rieur Appendix C - 3 :J3. 1 D9. D1O. Dll. 1 SEc:-:=~r D3 ~~-.-".",,,- -- ----- '1-".- '.""::.;.~.,....:..;..... '-: . -'u:. ":"':'...':'. ~ei:~e: ?3.::~: shall ""oiu.::3.:ily assign :::.:.s ':"gre:meAt or any pa..r: :~ereoi wit:-.o~t the written consent of the ocher ?a.rty, except i: :::onnection 'Wit.":. the sale or merger of a s~bsta.nci&l portion of its properties. -SEC:-:ON Dq NO :n:=:c.; 7!ON OF F ACr:.:-:-:!:S Aa.~/I.:.::.:er:ai::.; by one Paz":",.. to the other ~er a.ny provision of t~is Agreement sha..U ::.ot consti:~:e the cedic&tion of the SYStec:. or Uly por:ion thereof of either Pa.rrr co the public or to the acer ?a.r:;, a.nd i: is underStood a.nd a.greed t!:a: a:y sue.:. U:1der:a.ki::.; by eicller ?a.r:y sb.a.l.l cea.se ~pon the ce", "~a :ion 01 ::is Ag:e e=..e::. SZ:C7:~N D1O 7:~!:.D PARTY R!GE7S No~":.i::.g i::. t:.is Agreement sha.ll be construed to eXtend any benel1u to, or create a. ca.~se of a.ction by, any thi:d party. SEC':':ON Dll Ci.c:NE?-o\L PROVISIONS 7he cO:n;:ensa.tio::.. :a.tes, charges. terms and conditions a.s speciiieci herein sha.l.l rema.in in euect for the tere of this Agreemen: and shail ::.ct be s~bject :0 cha.nge through filing with, Appendix C - 5 DfS1 ?rovidec so i:J:'~g as :~e ca?acili:y ot the cransmission facilities is not i::-:';:3.i:eci 0:' -: .;.::son s continuity 01 service is not jeopa.rdi:eci therecy. S~C7:0N D13 TRANSMISSION L!..'lE Dl:3. 1 'I'~cson he reby consents to M-R.' s future right to construct a tra.nsrr..ission line to connect with the Sa-n J~&n ... Switc:yarc subject to the ioUowing conditions (. ) :ha: M-a or its affiliates pay the entire coSt of s.id conStruction and that no costs J. -be bor:1e by 'I'~cson: (0 )th.t said i:1te rconnection with the switc:.,a.rd be made so .. not to ict:l~r sy.tem ca.pa.bility. jeapa.rdi:e the conti:1uity of service. or restrict 7~csan I S ability to transact .Rith t:ard ?ar:ies a.t t.~e Sa.n Ju.n Swi.tc:.,ard: and (c)tha.t M-a obtain concurrence of PNM. IN WI7NE-SS WHEE.EOF. the Parties ha.ve ca.usee this Agreement to be executed as oi the Z9th day of November . 1 98 a PUBLIC ?OW~R AG:E:NCY By g/' (7;~ '- ' Appendix C - 7 DC7) APPENDIX D =~'I':;:~:::;:U:c:: :::: j;G ~-;=":".~::':' be~ween ':'::CSC:: E:.Z=!'.!C ?OWE? C::-!!'A!:Y and M-S-R PUBL:C POWER AGEN~1 SERVICE SCHEDULE RESERVE SHARING This Service Schedule E is aqreed upon as par~ of the Inter- connec~~=n Aqreemen~ en~ereci into between TUCSON E~==~C POWER COMPANY ("Tucson II ) anti M-S-R PUBLIC POWER AGENCY ("M-S-R" This Service Schedule E snail ):)e deemed ef:ec~ve when the purc.~ase of an undivided 28.8\ ownership interes~ in San Juan Genera t~~q S ta tion Unit No. ( " Uni t No.) from PNM is completed by M-S-R.This Service S~~edule shall ):)e in effec~ ~~ereafter fer the life of Unit No.4 or ~~til terminated by ei~~er Par~j upon three (3) years advance wri ~ten notice. 'C" .., -.. ~his Service Schedule E sets for~~ the ter=~ and condi- ticns under which the Par~ies shall share ~~e reserve capacity and ~~e reserve liability associated wi~~ and occasioned by their respective ownership interest in unit No.4 and in San Juan Generatinq Station Unit No.1 and Unit No.2 ("Unit No.1" and .. Uni t No. : " ) . It is contamplated that M-S-~ will acquire an undivided 28.8\ ownership i~terest in Unit No. ~ on May 1,1995.said 28. ownership interest in Unit No.4 is est i~a ted to be 138 ~~ of capaci t7 and energy.When M~~-R acq~:es said ownershi; interest ~n Uni~ No. ~, the Par~ies here~y agree ~~at M-S-R will assiqn tor0,~~~\rn~Appendix'D - ;:. -; Sta=~-up energy obli;a~iQns :0: the M-S-R snare of Un:' ~ ~:o. ~ will ~e f:::.ished to PNM by M-S-R and s~a:~-up enerqy o~li;a~:'Qns :0: ~~e T~cson share of Unit No.1 and Un:' ~ No.2 will be :~~:.shed to PNM by Tucson. When Unit No.4 is dawn. Tucson will schedule s~rt-up ener~J to PNM fer M-S-R.If Unit No.1 or Unit No.2 is oparatinq, M-S-R will schedule a like amount of energy from its capacity rights in said operating Unit to Tucson.If beth Unit Ne. 1 and Unit No.2 are not operat~~g, Tucson will maintain an account enerqy scheduled to PNM for M-S-R and M-S-R will return a like amcun~ of energy te Tucson within 60 days of the date that Unit No.1. Unit No.2 er Unit No.4 is retu:ned to service. In t.'1e event San Juan Unit-No.1 or Unit No.2 sboulcl be subj ected to an extended outaqe other than a normal maintenance outage, Tucson will assign an equal amount of Reserve Sharaq capacity to M-S-R from the other San Juan Unit until the San Juan Unit experiencing ~~e extended outage is returned to service. I:1 t.~e event San Juan Unit No.4 is subjec~ed to an extended outage other t:1a.n a normal maintenance ouaqe, M-S-R and T~cson will. four months after the start of the outage, sus- pend Reserve Sharing until San Juan Unit No.4 is retu..~ed, to .service. Executed this a3~d~y of ~, 19S,i. TUCSON E:U:C'rItIC POWER COMPANY --- '""' M-S-R PUBLIC PO\'lE:R AG~CY L~ //:-f/ Appendix D - 3 - ,..- -'" OW E R EX C H A N G E E X A M P L EX A M P L E 1 b As s u m p t I O n s . P a c l l l C o r p s c h e d u l e I r o m S a n J u a n = 1 2 , 00 0 M W h / m o n l h l o r 1 1 m o n l h s r c o n t r a c t y e a r . A d d l l 1 E n e r g y D e l i v e r y O p l i o n e l e c t e d b y R e d d i n g ( S 9 , 2 7 ) : I O p li o n 2 . S h o r l , Fa l l E n e r g y : R e d d i n g s c h e d u l e s 5 MW h 0 1 S e a s o n a l E n e r g y f o r 5 0 h o u r s i n A u g 01 2 0 0 0 ( S 92 2 4 ) De e Ja n Fe b Ma r Ap r Ma y Ju n Ju l Au g Se p Oc l No v ZO J l D no l i ZIl . ! J . Q ZO J l D ZO J l D ZO J l D ZO J l D ZO J l D ZO J l D ZO J l D ZO J l D ZO J l D lo L i l J PA C I F I C O R P . S a n J u a n E n e m y Am o u n l S c h e d u l e d . M W h 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 , 00 0 12 , 00 0 12 . 00 0 12 , 00 0 12 , 00 0 13 2 00 0 RE D D I N G . S e a s o n a l E n e r g y Ac c r u e d ( i n e ! , C . r r y - o v e r ) . " ' W h 12 . 00 0 00 0 12 . 00 0 12 , 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 10 . 00 0 13 0 00 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y , M W M " Am o u n l S c h e d u l e d I S 9 . 2 & 9 2 2 3 1 M W h lU S I I 16 . . Z ! I Q ZL S O I I ZL 5 . . O . . O 16 . 2S 0 16 . ZS 0 J Z O . OO O To l a l A c c r u e d a n d R e m a i n i n g . MW h 12 , 00 0 00 0 00 0 48 , 00 0 60 , 00 0 55 . 75 0 50 0 36 . 00 0 20 , 50 0 25 0 00 0 00 0 Ca r r y f o r w a r d 1 0 n e x t y e a r I I 92 2 6 ) , MW h 10 . 00 0 10 , 00 0 Bf D D I N G . A d d i t i o n a l E n e r g y Ac c r u e d W l n l e r E n e r g y I f t I , C . " y ' o v . , ) - MW h 50 0 50 0 Ac c r u e d S h o r l - Fa l l E n e r g y 0 MW h L5 1 1 lS O Ac c r u e d A d d i l i o n a l E n e r g y 0 M W h 75 0 50 0 25 0 Ma x H o u r t y R a l e 0 1 D e l i v e r y 11 1 0 2 1 . M W M " Ma x M o n l h l y A a l e o f D e l i v e r y ( S I O , 2) - "'W h / m o 10 . 30 0 10 , 30 0 10 , 30 0 30 0 10 . 30 0 30 0 Am o u n l S c h e d u l e d . M W h L5 0 IS O :: t To l a l A c c r u e d a n d A e m a l n l n g - MW h 75 0 75 0 75 0 50 0 50 0 Ca r r y f o r w a r d 1 0 n e x t y e a r ( I 9 , 61 - " ' W I t 50 0 1. 5 0 0 t'J YE m 2 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju l Au g Se p Oc l No y 2. . O . O . . l 2.. O . O . . l 2.. O . O . . l 2. . O . O . . l 2.. O . O . . l 2. . O . O . . l 2.. O . O . . l 2.. O . O . . l 2.. O . O . . l 2.. O . O . . l ZI M i l ZO I i l lo l i a l PA C I F I C O A P . S a n J u a n E n e r g y Am o u n l S c h e d u l e d . M W h 12 . 00 0 12 . 00 0 12 , 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 13 2 , 00 0 RE D D I N G . S e a s o n a l E n e r g y Ac c r u e d ( D e e In c I u d 8 s C . n y ~ Y 8 r ) . M W h 22 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 13 0 , 00 0 Ma x H o u r t y A a l e o f D e l i v e r y - M W M I r Am o u n l S c h e d u l e d - M W h LU l l lI . l l i ZL 5 . . O . . O 2U ! I 1 I 1B . . L 5 1 1 IB . . L 5 . . D 1 J I U I O O To l a l A c c r u e d a n d R e m a i n i n g - MW h 22 , 00 0 00 0 46 . 00 0 58 . 00 0 70 . 00 0 63 . 25 0 50 0 41 , 00 0 25 . 50 0 18 , 75 0 Ca r r y f o r w a r d 1 0 n e x t y e a r I I 9 , 61 - " ' W I t BE D D I N G . A d d i U o n a l E n e r g y Ac c r u e d W l n l e r E n e r g y ( f t i . C8 I 1 y - - 1 . MW h 50 0 00 0 10 . 50 0 Ac c r u e d S h o r t - Fa n E n e r g y . M W h Ac c r u e d A d d I l l o n a l E n e r g y 0 UW h 50 0 00 0 10 , 50 0 Ma x H o u r t y R I l l . 0 1 D e l M r y 1 1 1 0 , 2) . M W M v Ma . M o n t h l y R I l l . 0 1 D8 1 M t r y ( 1 ' 0 . 2 ) - M W t l l m o 10 , JO O 10 . 30 0 10 . 30 0 10 , JO O 10 . JO O 10 . 30 0 Am o u n t S c : h 8 c U 8 d . M W I 8 Ui I i I IU U 1 I I 1. U O O To f a l A c a u 8 d a n d R 8 m l I n l n Q . U W h 50 0 00 0 Ca r r y f o r w a r d 1 0 n . x t y e a r ( I 1 . 2 . 8) . M W h EX C HA N G XA H P L ~ ~ EX A M P L E 2 b As s u m p l l o n s ; . P a c l l i C o r p s c h e d u l e /r o m Sa n J u a n = 1 5 . 00 0 M W h l m C ! n l h lo r II m o n t h s er c o n l r a c t y e a r . . A d d U 1 E n e r g y D e l i v e r y O p t i o n e l e c t e d b y A e d d l n g I t 9 2 . 27 ) : 0 l i o n 2 . S h o r l , Fa l l E n e r g y : R e d d i n g s c h e d u l e s 5 MW h 0 1 S e a s o n a l E n e r g y l o r 5 0 h o u r s i n A u g 01 2 0 0 0 ( ~ 92 2 4 ) Yf A B . l De e Ja n Fe b Ma r Ap r Ma y Ju n Ju l Au g Sa p Oc l No v ZI 1 a ! ! 2.. 0 . . 0 0 2. . Q . O j I 2.. Q . O j I 2. . Q . O j I 2.. Q . O j I 2.. Q . O j I 2. . Q . O j I 2.. Q . O j I 2. . Q . O j I zo a ! ! ZO a ! ! l.D . l a l PA C I F I C O A P . S a n J u a n E n e m Y Am o u n t S c h e d u l e d . MW h 15 . 00 0 15 . 00 0 00 0 15 . 00 0 15 . 00 0 15 , 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 16 5 . 00 0 EO O I N G Se a s o n a l En c l Q ! ! Ac c r u e d ( l n d , C . . r y . o v e r ) . M W h 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 10 . 00 0 13 0 00 0 Ma x H o u r t y R a l e 0 1 D e l i v e r y . IA W t v t v Am o u n l S c h e d u l e d ( f 1 1 , 2 & 9 , 3) M W h lt i . l l . O 2. U i I 1 1 Z U ! l ! I Z: i 1 1 ZI 1 . 00 1 1 To l a l A c c r u e d a n d R e m a i n i n g . MW h 12 . 00 0 00 0 00 0 48 . 00 0 60 . 00 0 55 . 75 0 50 0 36 . 00 0 20 . 50 0 16 . 25 0 10 . 00 0 10 . 00 0 Ca r r y l o r w a r d t o n e l l t y e a r ( I 9 , 26 1 . M W h 10 . 00 0 HE 1 2 D I Ad d i U o n a l Er w g v Ac c r u e d W i n t e r E n e r Q Y (in d , C a r r y , o v e r l ' t . l W h 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 3. 7 5 0 26 , 25 0 Ac c r u e d S h o r l - Fa n E n e r g y - M W h il l 15 0 Ac c r u e d A d d i l i o n a l E n e r m . MW h 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 00 0 25 0 75 0 27 . 00 0 Ma x H o u r l y A a t e o t D e l i v e r y (1 1 0 2 1 . M W M u Ma x M o n t h l y R a t e 0 1 D e l i v e r y ( 1 1 0 , 21 . M W h / m o 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 30 0 10 . 30 0 Am o u n t S c h e d u l e d . M W h Z- Z 5 1 1 Z- Z : i . . D Z- Z 5 i l ~I I J I I . Ja ! ! J2 . JO O II I To t a l A c c r u e d a n d A e m a l n i n g . M W h 25 0 25 0 25 0 25 0 25 0 50 0 75 0 00 0 12 . 00 0 25 0 25 0 70 0 70 0 Ca r r y l o r w a r d t o n e x t y e a r ( I 9 . 61 0 M W h 70 0 70 0 YE A E L 2 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju l Au g Se p Oc t Na y ZO O J ZO O J ZO O J ZO O J ZO O J 2. Q . O J ZO O J rn u . ZO O J ZO O J ZO O J ZI I O J Ig l a J PA C I F I C O A P . S a n J u a n E n e m Y Am o u n t S c h e d u l e d . MW h 00 0 15 . 00 0 15 . 00 0 t5 . 00 0 15 . 00 0 t5 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 16 5 . 00 0 RE D D I N G - S e a s o n a l E n e r g y Ac c r u e d ( D e e h c I u d e t C a n y ~ V l l r ) - M W h 22 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 13 1 1 . Ma x H o u r t y R a t e 0 1 D e l i v e r y . IA W t v t v Am o u n t S c h e d u l e d - M W h JL i l l JL i l l ZU ! l . I I ZU ! l . I I ~I I JJ I I . II I I O To t a l A c c r u e d I n d R e m a i n i n g 0 MW h 22 . 00 0 00 0 46 . 00 0 58 . 00 0 70 . 00 0 63 . 25 0 56 . 50 0 41 . 00 0 25 , 50 0 18 . 75 0 Ca r r y l o r w l r d t o n e x t y e a r ( f 1 1 , 6) . t . l W h RE D D I N G Ad d i U o n a l E/ w m ! Ac c r u e d W i n t e r E n e r g y ( i n d , Ca r r y , o v e r l . M W h 95 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 45 0 Ac c r u e d S h o r H a n E n e r g y . MW h Ac c r u e d A d d l l i o n a l E n e r g y . U W h 95 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 25 0 41 . 4 5 0 Ma x H o u r t y R a l e 0 1 D e l i v e r y ( 1 1 0 2 1 . M W M \ I Ma x M o n t h l y R a t e 0 1 D e l i v e r y ( 1 1 0 , 21 . M W h l m o 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 Am o u n t S c h e d u l e d . M W h ~n g 2. l l I I 2. l l I I 2. l l I I 10 . 30 0 Zz . O O I l To t l l A c c r u e d 8n d Re m a i n i n g . M W h 95 0 25 0 25 0 25 0 25 0 50 0 75 0 00 0 25 0 13 . 50 0 75 0 14 . 45 0 14 . 45 0 Cl r r y l o r w a r d 1 0 n e x t y e l r ( I 9 . 2 . 61 0 t . f W h 45 0 45 0 HA N EX A M E: i EX A M P L E 3 b As s u m p t i o n s : . P a c i h C o r p s c h e d u l e h o m S a n J u a n = v a r i o u s m o n t h l y a m o u n t ' . A d d l " E n e r g y D e l i v e r y O p l i o n el e c t e d b y R e d d i n g ( t 9 . 7) : I O D l i o n 2 I . S h o r 1 , Fa l l E n e r g y : R e d d i n g a c c r u e s v a n o u s a m o u n t ' 01 S h o r 1 , Fa l l E n e r g y I t 92 2 4 ) Yf M l l De e Ja n Fc b Ma r Ap r Ma y Ju n Ju l Au g Se p Oc l No v ZO Q . O ni l 0 ZO O O Wl I l Wl I l Wl I l Wl I l Wl I l Wl I l Z2 0 1 l lO O n ZO l l O l! J l a l PA C I F I C O R P . S a n J u a n E n e r a v Am o u n l S c h e d u l e d . M W h 15 , 50 0 15 . 00 0 00 0 12 . 00 0 00 0 50 0 50 0 ' 1 5 . 60 0 16 . 00 0 12 . 00 0 90 0 13 0 . 00 0 RE D D I N G . S e a s o n a l E n e r a v Ac c r u e d ( i 1 d , C8 R y - o v e r ) . M W h 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 00 0 50 0 50 0 12 . 00 0 12 . 00 0 12 . 00 0 90 0 11 3 . 90 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y . M W M I r Am o u n l S c h e d u l e d ( I 9 , 2 & 9 , 23 1 U W h Jl i ~ O lR . r u 1 ZM I l J I ZM I l J I lL Z 5 0 Hi . Z5 0 10 5 . 00 0 To l a l A c c r u e d a n d R e m a i n i n g . U W h 12 . 00 0 00 0 00 0 00 0 55 , 00 0 45 , 25 0 36 . 50 0 28 . 50 0 20 . 50 0 16 . 25 0 90 0 90 0 Ca r r y l o r w a r d 1 0 n e x ! y e a r I I 9 2 2 6 1 . MW h 90 0 !I " O BE 1 2 D 1 l l i i . Ad d i l i o n a l .f n e r g x Ac c r u e d W l n l e r E n e r Q Y (i 1 d . C a r r y . o v e r I . M W h 62 5 25 0 50 0 70 0 00 0 12 . 01 5 Ac c r u e d S h o r l . Fa l l E n e r ! l y . M W h 50 0 :I S O 55 0 UO O Ac c r u e d A d d l l i o n a l E n e r g y . MW h 62 5 25 0 50 0 50 0 35 0 70 0 00 0 55 0 13 . 47 5 Ma l l H o u r l y R a l e 0 1 D e l i v e r y ( 1 1 0 2t . M W M u Ma x M o n l h l y R a l e 0 1 De l i \ / ' 8 r y 1 1 1 0 . 21 ' UW h / m o 10 . 30 0 10 . 30 0 10 . 30 0 30 0 10 . 30 0 to . 30 0 't I Am o u n t S c h e d u l e d . M W h z. I i Z S z. Z S O 1. ~ Li l l O IJ . 'I l : : ' To t a l A c c r u e d a n d R e m a i n i n g . U W h 62 5 25 0 50 0 50 0 85 0 55 0 55 0 5! 1 0 , t O O c:L Ca r r y r o r w a r d 1 0 n e x ! y e a r ( I 9 . 61 . U W h I1 J Yf M l 2 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju t Au g Se p Oc t No v ZQ . O . l ZQ . O . l ZQ . O . l WI . 1 WI . 1 WI . 1 WI . 1 WI . 1 Z2 1 U WI . 1 z. o I U ZO I i l Ia l a l 0'\ PA C I F I C O R P . S a n J u a n E n e r a v Am o u n l ~u l e d . MW h 00 0 15 , 50 0 15 . 00 0 00 0 50 0 50 0 00 0 15 , 00 0 16 . 00 0 15 . 00 0 50 0 00 0 13 0 . 00 0 RE D D I N G Se a s o n a l Ac c r u e d ( D e e n d u d e l C 8 R y - G v e r l . M W h 20 , 90 0 12 , 00 0 12 . 00 0 12 , 00 0 50 0 50 0 00 0 12 . 00 0 12 . 00 0 12 . 00 0 50 0 00 0 11 8 . 40 0 Ma x H o u r l y R a t e o f D e l i v e r y . U W M ! r Am o u n l S c h e d u l e d , M W h 1i . l l i n. o . o O 16 . 2 5 0 ll i . 2 S 0 1I . 1 i . , , ./ . To l a l A c c r u e d a n d R e m a i n i n g . U W h 20 . 90 0 32 , 90 0 90 0 56 . 90 0 63 . 40 0 53 . 65 0 45 . 40 0 32 . 40 0 18 , 00 0 13 . 75 0 00 0 00 0 Ca r r y r o r w a r d 1 0 n e x ! y e a r ( I 9 , 6) . M W h 00 0 00 0 RE D D I N G Ad d i U o n a l , A c c r u e d W l n l e r E n e r g y ( i 1 d , Ca r r y . o v e r ) . U W h 50 0 62 5 25 0 50 0 25 0 00 0 25 0 15 . 37 5 Ac c r u e d S h o r t . Fa l E n e r g y . UW h SO O so . . o ZO O 1. Z ! l 1 I Ac c r u e d A d d i l i o n a l E n e r g y . U W h 50 0 62 5 25 0 50 0 50 0 50 0 25 0 00 0 25 0 20 0 16 . 57 5 Ma l l H o u r l y R a l e o r D e l i v e r y ( 1 1 0 . 2) . M W M I r Ma x M o n l l l y R a l e 0 1 De l i v e r y 1 1 1 0 , 2) . M W h l m o 10 , 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 10 . 30 0 Am o u n l S c : h e d u I e d . M W h 1. 9 0 2. . W 2. U I I UJ H I Zo o JU l J i To l a l A c c r u e d a n d R e r n l l n l n g . MW h 50 0 62 5 25 0 1. 5 0 0 50 0 00 0 25 0 25 0 50 0 70 0 Ca r r y l o r w a r d 1 0 n e x ! y e a r ( 1 9 , 6) . U W h APPEND:IX F EXAMPLE CALCULAT:ION ESTABL:ISB:ING ADJUSTMENTS FOR :INTEREST Simple interest "Mid-year Convention II shall be utilized in calculating the amount of the adjustments for interest. Assum'Dtions For Exam'D1e Calculations:(1) Total Annual Payment Difference for Contract Year December 1, 1996 through November 30, 1997(2) Prime Ratell) (3) Time of Adjustment $12,000 October 1, 1998 Ad;ustments For Interest: Prime Rate.i.ll. Interest Rate Dec 1996-Nov 1997 Dec 1997-Sep 1998 Eactorl2) 0% mul tiplied by 0% mul tiplied by 1/2 10/12 50% 50% 12.00%12.00% x $12,000 = $~D Adjustment For Interest (1 )The prime rate shall be the time weighted average prime ratefor the period. For the example above it would be for the period January 1996 through September 1998. The prime rateshall be as established by 1) Morgan Guaranty Trust Company ofNew York, or 2) mutual agreement of the Parties. (2 )December 1996-November 1996 December 1997 -September 1998 mid-year convention 1/2 year 10 months Appendix F - 1 PO W E R E X C H A N G E E X A H P L E ~ EX A M P L E 3 8 As s u m p t i o n s : . P a c i l i C o r p s c h e d u l e l r o m S a n J u a n = v a r i o u s m o n l h l y a m o u n l s , . A d d i l 1 E n e r g y D e l i v e r y O p l i o n e l e c l e d b y R e d d i n g ( S 8 , 7) : I O p l i o n 1 I . S h o r t - Fa l l E n e r g y : R e d d i n g a c c r u e s va r I O u s a m o u n l s 0 1 S h o r t - Fa l l E n e r g y ( S 9 , 22 4 1 , YE M . 1 De e Ja n Fe b Ma t Ap r Ma y Ju n Ju l Au g Se p Oc l No v Z. o o . o 2.. Q 2 D 2. . Q 2 D Z a o . o Za o . o II 1 I a 1 PA C I F I C O R P - S a n J u a n E n e r Q Y Am o u n l S c h e d u l e d . MW h 15 . 50 0 15 . 00 0 14 . 00 0 12 . 00 0 00 0 50 0 50 0 15 . 60 0 16 . 00 0 12 . 00 0 90 0 13 0 00 0 RE D O I N G Se a s o n a l En e m v Ac c r u e d l o n d , C8 n Y - G " , ' 1 . M W h 12 , 00 0 12 . 00 0 00 0 12 . 00 0 00 0 50 0 50 0 12 . 00 0 12 , 00 0 12 . 00 0 90 0 11 3 . 90 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y . M W M v Am o u n l S c h e d u l e d ( I ! ' - 2 , 2 & 9 2 , 31 M W h .I I lu . . 5 . 1 1 1R . l l i 2i l J l O Q 20 . 0 0 . ( ) JL Z 5.. 0 1U 5 . . 0 .II 1. 0 5 . 00 0 To l a l A c c r u e d a n d R e m a i n I n g . MW h 12 , 00 0 00 0 36 . 00 0 48 . 00 0 55 . 00 0 25 0 36 , 50 0 28 , 50 0 50 0 16 , 25 0 90 0 90 0 Ca r r y l o r w a r d 1 0 n e x t v e a r / I 92 2 6 1 - M W h 90 0 90 0 Bf O D I ~ Ad d i t i o n a l fn e U I X Ac c r u e d W l n l e r E n e r g y ( n e t , C . r r y - o v e r l - MW h 50 0 00 0 00 0 60 0 00 0 Ac c r u e d S h o r l . Fa l l E n e r g y . MW h .I I ~. I I . o ~. o :i ~ 0 !! I t 1 l Ac c r u e d A d d i t i o n a l E n e r g y . MW h 50 0 00 0 00 0 50 0 35 0 60 0 00 0 55 0 17 . 50 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y / l I D 21 . M W M " :x : - Ma x M o n l h l y R a l e 0 1 D e l i v e r y 1 1 ' 0 , 21 . M W h / m o 15 5 32 5 68 5 Am o u n l S c h e d u l e d . MW h II l. . . t l l 1. . 3 2 5 68 5 16 . Hi : i To l a l A c c r u e d a n d R e m a i n i n g . M W h 50 0 50 0 50 0 34 5 52 0 87 0 47 0 47 0 47 0 02 0 33 5 33 5 Ca r r y l o r w a r d 1 0 n e x ! v e a r / I 9 , 61 . M W h 33 5 33 5 YE M l 2 De e Ja n Fe b Ma r Ap I Ma y Ju n Ju l Au g Se p Oc l No v Z. Q J l 1 Z.Q J l 1 Z. Q J l 1 Z.I I J I . 1 Z. Q J l 1 Z. Q J l 1 Z.I I J I . 1 Z.I I J I . 1 Z.Q J l 1 ZJ l O . 1 Z. o O . 1 ZI I O . 1 Il I l a i lJ 1 PA C I F I C O R P . S a n J u a n E n e r o v Am o u n l S c h e d u l e d . MW h 14 . 00 0 15 . 50 0 15 . 00 0 00 0 50 0 50 0 00 0 15 . 00 0 16 . 00 0 15 . 00 0 50 0 00 0 13 0 00 0 RE D O I N G - S e a s o n a l E n e r Q Y Ac c r u e d ( D e e nc u t H C8 n Y - G W l r l . M W h 20 , 90 0 12 . 00 0 12 , 00 0 12 , 00 0 50 0 50 0 00 0 12 , 00 0 12 . 00 0 12 , 00 0 50 0 00 0 11 8 , 40 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y . M W M v Am o u n t S c h e d u l e d . M W h .II lU S I I 1U 5 1 1 25 . . l I . O . . I I ll . Z 5 . o 1! i . Z:i . o .I I 11 6 . 40 0 To l a l A c c r u e d a n d R e m a i n i n g . M W h 20 . 90 0 32 . 90 0 44 , 90 0 90 0 63 . 40 0 53 . 65 0 45 . 40 0 32 . 40 0 t 8 . 00 0 t 3 . 7 5 0 00 0 Ca r r y 1 0 r w a r d t o n e x ! y e a r / I 9 . 61 . M W h 00 0 00 0 BE D D I N G . A d d i U o n a l E n e r o v Ac c r u e d W i n t e r E n e r g y ( i n c t . C . " y - o v 8 r l . MW h 33 5 50 0 00 0 00 0 00 1 ) 00 0 00 0 83 5 Ac c r u e d S h o r l . Fa . E n e r l l Y . M W h ~o . o 50 . 0 za l l Lz o a Ac c r u e d A d d i t i o n a l E n e r l l Y . M W h 33 5 50 0 00 0 00 0 50 0 50 0 00 0 00 0 00 0 20 0 23 . 03 5 Ma x H o u r l y R a l e 0 1 D e l i v e r y 1 1 1 0 , 21 . M W M t r Ma x M o n t h l y R a t e 0 1 D e l i v e r y 1 1 1 0 , 21 . M W h / m o 41 0 91 5 10 . 07 0 Am o u n t S c h e d u l e d . M W h Ut . I I 2. l , U 1. 1 1 . 11 1 a ZU ! i 5 To l a l A c c r u e d a n d R e m a i n i n g . M W h 33 5 83 5 83 5 35 5 44 0 94 0 44 0 44 0 44 0 11 . 44 0 64 0 57 0 57 0 Ca r r y l o r w a r d t o n e x ! v e a r / I 9 , 61 . M W h 57 0 57 0 OW E R E CH A N G E E X A M P L EX A M P L E 2 8 As s u m p l l o n s : . P a c i l i C o r p s c h e d u l e h a m S a n J u a n = 1 5 . 00 0 M W h l m I ? " l h l o r I I m o n l h s r c o n l r a c l y e a r . A d d i l ' l E n e r g y De U v e r y O p l l o n e l e c t e d b y R e d d i n g I S 9 2 , 7) : li o n 1 . S h o r t , Fa l l E n e r g y : R e d d i n g s c h e d u l e s 5 MW h 0 1 S e a s o n a l E n e r p y l o r 5 0 h o u r s i n A u g 0 1 2 0 0 0 I ~ 92 2 4 1 YE ! 8 . 1 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju t Au g Se p Oc l Na v ~a o ZQ D O ZJ l Q D ZJ l Q D ZJ l Q D ~O D ~Q D ZJ l Q D ZJ l Q D ZM O ZO l l O ZO l l O Is / l i i ! PA C I F I C O R P - S a n J u a n E n e m Y Am o u n l S c h e d u l e d . M W h 15 . 00 0 15 , 00 0 15 . 00 0 15 , 00 0 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 , 00 0 15 , 00 0 15 . 00 0 16 5 , 00 0 RE D O I N G Se a s o n a l .E n A m x Ac c r u e d l i n d , Ca r r y - ' - MW h 12 . 00 0 12 , 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 00 0 13 0 00 0 Ma w H o u r l y R a l e 0 1 D e l i v e r y . t.C W M 1 r Am o u n l S c h e d u l e d I S 9 , 2 & 9 . 31 M W h l6 . f i Q l6 . f i Q ZU O Q ZL ~ l6 . f i Q ti . Z ~ O lZ 2 . . I I Q Q To l a l A c c r u e d a n d R e m a i n i n g . MW h 12 . 00 0 00 0 36 , 00 0 48 . 00 0 60 , 00 0 55 . 75 0 5 I . 50 0 36 . 00 0 20 , 50 0 16 . 25 0 00 0 10 , 00 0 Ca r r y l o r w a r d t o n e x t y e a r I S 9 2 , 61 . M W h 10 , 00 0 10 . 00 0 DD I N G Ad d i l i o n a l .E n g r g x Ac c r u e d W i n t e r E n e r ! l y l i n d . Ca r r y - o v e r ' . M W h 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 Ac c r u e d S h o r t - Fi l l E n e r g y . MW h il l lO t . Ac c r u e d A d d l l i o n a l E n e r g y . MW h 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 75 0 00 0 00 0 35 , 75 0 MI x H o u r l y R a t e 0 1 D e l i v e r y IS I D 2 ' . M W M 1 I MI X M o n l h l y R a l e 0 1 D e l i v e r y I S 1 0 , 21 . M W h i m o 68 5 71 0 13 . 25 0 Am o u n t S c h e d u l e d . MW h :J . ll a 1: 1 , Z5 1 1 Z4 . 64 5 't J To l a l A c c r u e d e n d R e m a i n i n g . MW h 00 0 00 0 00 0 31 5 60 5 60 5 60 5 12 , 60 5 16 , 35 5 19 . 35 5 19 . 35 5 11 . 1 0 5 , 1 0 5 :: I Ca r r y l o r w a r d t o n e x t y e a r I I 9 , 61 . M W h 10 5 11 . 10 5 .. . . tI I YE M 2 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju t Au g Se p Oc l Na v ~1 1 . . 1 z.Q . I I . . 1 z.Q . I I . . 1 z.Q . I I . . 1 z. Q . I I . . 1 z.Q . I I . . 1 z.Q . I I . . 1 z. Q . I I . . 1 z.Q . I I . . 1 z.Q . I I . . 1 ~1 1 . . 1 Z! ! . I I . . 1 Io t a ! l6 J PA C I F I C O R P - S a n J u a n E n e m Y Am o u n t S c h e d u l e d . M W h 15 . 00 0 t5 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 . 00 0 15 , 00 0 15 . 00 0 15 . 00 0 16 5 , 00 0 RE D O I N G . S e a s o n a l En e ~ Ac c r u e d ( D e e n c b t e l C. , . , - o . . r ) . UW h 22 , 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 13 0 . 00 0 MI x H o u r l y R i l e o f D e l i v e r y . MW I I I h r Am o u n t S c h e d u l e d . M W h 1L l l i 1L l l i 2U J I J I 2U J I J I 1L l l i J. . i . l i I I J3 1 l . PQ I I To l a l A c c r u e d e n d R e m a i n i n g . U W h 22 . 00 0 34 . 00 0 46 . 00 0 58 . 00 0 70 . 00 0 63 . 25 0 56 , 50 0 41 . 00 0 25 . 50 0 18 . 75 0 Ca r r y l o r w l r d 1 0 n e x t v e e r 1 1 1 1 . 2 , 8) . M W h BE D D I Ad d l U o n 8 1 E n e r v v Ac c r u e d W i n t e r E n e r g y ( I n d . Ca r r y - o v e , ) . M W h 14 . 10 5 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 15 , 00 0 56 , 10 5 Ac c r u e d S h o r t - Fl . E n e r g y - MW h Ac c r u e d A d d I t i o n a l E n e r g y . M W h 10 5 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 00 0 15 . 00 0 !i 6 . 10 5 MI X H o u r l y R I t e 0 1 D e l i v e r y 1 1 1 0 . 21 . M W M v MI x M o n t h l y R i t e 0 1 D e U v e r y ( 1 1 0 . 21 - M W h l m o 13 . 25 0 48 0 13 . 25 0 Am o u n t S c : t I e c U 8 d - t . I W h n. w 13 . l l 1 1 :J u a o To t l l A c : c r u 8 d I n d Re m I I r * 1 g . MW h 10 5 t7 . 1 0 5 20 . 10 5 85 5 37 5 37 5 10 . 37 5 13 . 37 5 16 . 37 5 18 . 37 5 34 . 37 5 21 . 12 5 2 1 . 12 5 Cl r r y l o r w e n t 1 0 n e x t y e l l ' ( I 1 . 2 . 8) . M W h 21 . 12 5 2 t , I 2 5 PO W E R E X C H A H O E E X A M LE S EX A M P L E ' a As s u m p t i o n s . P a c i l i C o r p s c h e d u l e f r o m S a n J u a n = 1 2 . 00 0 M W h l m o n l h l o r 1 1 m o n l h s er c o n l r a c l y e a r , . A d d i n E n e r g y D e l i v e r y O p l i O n el e e l e d b y R e d d i n g ( S 9 2 , 7) : li o n 1 . S h o r t - Fa l l E n e r g y : R e d d i n g s c h e d u l e s 5 MW h 01 Se a s o n a l E n e r g y l o r 5 0 h o u r s I n A u g 01 2 0 0 0 I S 9 2 2 4 ) :t f m J De e Ja n Fe b Ma r Ap r Ma y Ju n Ju l Au g Se p Oc l No v ZI l . O . O ZO O O ZO I l . O . ZO I l . O . ZI l . O . . O ZI l . O . O ZU O ZI l . O . . O ZU O ZU O ZU O ZO O O fI l I a l PA C I F l C O R p Sa n J u a n Am o u n l S c h e d u l e d . M W h 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 , 00 0 13 2 . 00 0 ED D I N G Se a s o n a l Ac c r u e d ( i n d , Ca r r y _ ) . M W h 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 10 . 00 0 13 0 . 00 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y . M W M v Am o u n l S c h e d u l e d I I 9 . 2 1 9 , 31 M W h a. ~ 0 !u s o ZL S O O ZL S Q . O iU S D t. 6 . l 5 0 lZ 0 . 00 0 To l a l A c c r u e d a n d R e m a i n i n g - MW h 12 , 00 0 00 0 36 . 00 0 46 . 00 0 60 . 00 0 55 . 75 0 51 . 50 0 36 . 00 0 50 0 16 . 25 0 10 , 00 0 00 0 Ca r r y l o r w a r d 1 0 n e J d y e a r I I 9 . 61 . M W h 10 . 00 0 10 . 00 0 DD I N G . A dd i l i o n a l .E l w 1 l ! ! Ac c r u e d W i n l e r E n e r A V ( i n d , Ca ' r y - o w u l . M W h 00 0 00 0 Ac c r u e d S h o r t . Fa l l E n e r g y . MW h rn I l. 5 0 Ac c r u e d A d d i l i o n a l E n e r A V . M W h 75 0 00 0 75 0 Ma x H o u r l y R a l e 0 1 D e l i v e r y 11 1 0 2 ) . M W M I r ~ M a x Mo n l h l y R a l e 0 1 D e l i v e r y 1 1 1 0 , 2) . M W h / m o 32 5 :s A m o u n l S c h e d u l e d . MW h l. 5 D Z~ O To l a l A c c r u e d a n d R e m a i n i n g . MW h 75 0 75 0 75 0 00 0 00 0 Ca r r y f o r w a r d f a n e J d y e a r I I 9 , 6) . M W h 00 0 00 0 .. . . r1 I Yf A B . . 2 De e Ja n Fe b Ma r Ap r Ma y Ju n Ju t Au g Se p Oc l No y ZI l . O . 1 ZO D l ZO D l ZO D l ZO D l ZO D l ZO D l ZO D l ZO D l ZO D l ZO D l ZD n l li I l a J t- ' PA C I F I C O R P - S a n J u a n E n e f O Y Am o u n f S c h e d u l e d . M W h 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 13 2 . 00 0 RE D D I N G . S e a s o n a l E n e r o v Ac c r u e d (D e e : I n c I u d I I 8 C a r r y - o v e r ) . M W h 22 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 , 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 12 . 00 0 13 0 . 00 0 Ma x H o u r l y R a l e o f D e l i v e r y . M W h I h r Am o u n l S c h e d u l e d . M W h 1L 1 ~ 1. D . l l Q 2. U G 2. U G 1. D . l l Q 1.I . . . l . 5 0 t 3 1 1 . 0 0 0 To l a l A c c r u e d a n d R e m a i n i n g - MW h 22 . 00 0 00 0 46 . 00 0 56 . 00 0 70 , 00 0 63 . 25 0 56 . 50 0 41 , 00 0 25 . 50 0 18 . 75 0 Ca r r y f o r w a r d 1 0 n e J d y e a r I I 9 , 8) . M W h RE D D I N G . A d d i U o n a l E n e r o y Ac c r u e d W i n l e r E n e r g y ( i n c l . C8 I r y - o v e r ) . M W h 00 0 12 . 00 0 00 0 Ac c r u e d S h o r t . Fa U E n e r g y . M W h Ac c r u e d A d d I l l o n a l E n e r g y . M W h 00 0 12 . 00 0 14 . 00 0 Ma . H o u r t v R a I . o r De I l w 8 r y 1 1 1 0 . 2 ) . M W M v Ma . M o n I h l y R a I . 0 1 De I I v 8 r y 1 1 1 0 . 2 ) . M W h I m o 59 0 32 5 10 . 33 5 Am o u n t S c h e d u l e d . M W h UI I 1U 3 5 12 . . . 3 J 5 To l a l A c c r u e d a n d R e m I I l n l n g - MW h 00 0 00 0 00 0 41 0 12 . 00 0 66 5 66 5 Ca r r y f o r w a r d 1 0 n e J d y e a r ( I 9 . 8) . M W h 66 5 66 5 -- --- -----.... t"'-:--~=~ une-na~.: c= ~-5-=-.capac:::-:t r:.;ntsi~ t.:~: No. anci ~=~c~ wi~: i~ :~-: ass~;~ ~O M-S-R === reserve ;:n:_::cses an equal ~=: ::: ':'-.:cson 'capac:'::t ri;h:s i~ Unit No. anc. tJ~:.: ~o. ... .. is rec=;~:ec. :~~: :tis Serv:.ce Schedule E is entered i::= ==r the pu...-;ose 0: reQ~=:.n; ~~e reserve requirements of M-S-R and. ':~cson only and i: is understood. t.b.a.t no ownership r:.qhts are in any way to be affected by this Ser:ice Schedule t. It is understood ~~at M-S-R will count as capacity one-hal= 0 f its generation en ti tlemen: in Unit No.4 and one quarter in each 0: Un:': No. : and Uni: No. :. and wil~ schedule ==0: these uni~ ~ased on ~~eir availability.For purposes of enerqy accou~g, M-S-R hourly energy ~enti:lements shall be deter- mined by multi~lyin; ~~e M-S-R parti=i~ation percentage expressed as a decimal quanti:y by Unit No.'; hourly capability less the J-S-R hourly cur-.:1ilment of Unit No.1 and Unit No.2 less the M-S-R hourly cu:tail:1en: 0: Unit No.Energy schedules will be adjusted to reduce i:balances in the course of the year =ased on the M- 5- R energy en ~ :lemen tz .Adjus~ents in the deliveriesof ener;-.t to M-S-R c.;i.~g :he :i=~t two =n~s 0: the succeeding calenda: year will be made based upon ~~e year end equali:aticn. ':~s tWO-tICn~~ period may be extended by mutual aqree- men: 0: the Operati=ns Cc~~i ttee i: winter or sp::.:; maintenance is scheduled on Un:.: No. :. Uni t No.2 or Uni t No.4 and. the resu.lti~q energy shi:: is i~ a ~alancing direct~Qn. 1:.No time li:i: wil1 be placed on ~~e sha=i~g 0: reserves ~n Uni: No. :.. Un:': No. : or Unit No. .;. However. energy i=bal- ances resu.l~~; :=== :~e shari~; 0: reserves will be l ~ed to ~~e ene=~. equi~al~~: c: 60 ciays I operati=n a: ~:O percen: capa- ~i~v :ac~~~ o~era~=~ c: one-hal= ::: ~~e M-S-R en::.:lement Appendix D - 2 TUCSON E1..Z'::-?.IC ?OWE::.. C::MPANY --0 '"' - Appendix C - 8 DCS) ~ll. :n z. or a.??iic3.::'o~ :0, :~e ?ecieral 2~ergy ?egu.i.atc:y C~r:-.:nission ?u:suant to t~e p::::1'.-isi=~s of Section 2.05 ot the Federal ?ower Ac: absent the mu:~al agreement 01 the Parties hereto.Neither Party shall :equest or i.=.itiate. directly or indirectly, action by said Comcission f:::1r any change herein pursuant to Section ,06(a) of said Act. It i~ W1cer s:ood......nd agreed that this A greement is predicated upon the a,Ssum;::lon th3.t M-r.. ..ctuaUy exercises its Opcioa. to ac~ulre an \mdivi':!ed 2.3.8 percent ownership i~ t!le S6n JIJoa.a. .. and :elateci preper:, i:uerests.I.c1 'the event that M-R does not exerci:se its said Option and dees c.Ot a.c~uire ownership in s&i.d San JlJoan 4, then::.:.s Agreecen: si:1a.ll be c.ull a.nd void and of no e!!ec:. SZC7::JN 012 USE ::F :::AN ;:;AN SV!I7::EYAP.D 7lJocsoc. agrees that ?OWer c!elivered by M-R from its interest i: Sac. J\Jan 4 to the Sac. JlJoan Switc::yard v.rill be made available upon :equest 01 M-r.. to M-R or to third parties ..t t.":.e San Juan Swi.tchya.rc. up to 144 mega.wa.tts oi ca.paci:v. at times when :b.e power exc~nge described herein is not being ma.de a.t FVNC,S,S. the Moen.itopi Substation. or the WestWing Switchyard. it being underStood t!lat such. availability will be Appendix C - 6 0(6) D5. Dc. --- D7. twenty-fou: \2';') ~ou: schedule. S~C:7:0N !J S?O~TrS1 OF DE:!...:VE:?Y The ?oi::.:( s) 01 Delive ry for t:~ns3oc::ions hereunder shall be: ( a.)Froe M-R to Tu.cson 3ot the S3on Ju.a.n Cener~t:.::g St~tion 345 kV Switc:ya.rd. (b)::or: ::-~c:son :0 M-R a.t PV'NG:s3. the Mcenito~:. SuCst3oticn. or the We .raring Swirc=..,ard. .. - (c:)Other ?oi::: of delivery as the Oper~:i::.g r-..-.o ::ee represe.nCLtives c.a.y r::.u:~ly agree upon. SE:C:7:~N ~6 LOSS~S There are no 10s se s as soci~ted with the capacity and energy deli...eries ma.de to TL.1cscn at S-.n Ju.a.n and to M- at PVNGSS. :~e Moenito~i SL.1bstatioc. or the Westwing Switch- ya.rc. S~C:7:0N D7 CHARGES There snail be co ch~:ge! a.sscciated with the delivery of ca~a.ci:v anc energy associa.ted with this Agreement. Appendix C - 4 "'" , . , :Jl. :H. : :;)2. : ------..., -,.:::.~ - - -..... 7uc.sC:l ~= ~. r.. desi:e to exc::Lnge M-s snare of capacity ana associated energy !:o::-. the net power p:odUC::'OA 01 Sa.n :ua.n 4 Eor a. like a.mount oi capacity and energy a.t PVNCSS. t.~e Moenkopi Substation. or the We stwing Switc:- ya.rc!. 7boe Part:.es recogni:e that !:om ti=e to ti=e there may be scneci.wec 0 r' ~on.sc::'eciuleci outa.ge..s u!ec:i:.g the out?\:: oi,A . San Jl.1a.n U:i: 4.E:ac: ?3.r~ a.grees to use its best efforts to nct:i-~.. t::..e ocer ?:u-:-,.. s ~l'::::iently i:. a.dvance 01 sc::.eciuleci OUCLges and to CO::ec: all :onsc::.eciuled out:Lge s a.s soon a.s pra.c:'i::LOle so a.s :0 er.~le t.:.e exc~ge oi c3.pac:.:-r a.:1C energy to t3.Ke ~;.a:::e oeCWeen :'::'e ?a.:::.es as provic:iec ::.erein. S!:C7:0N DZ 1'!:?. The exc~::.ge ::ac.e u.-:.der :.:.is Agreement sha.ll be to: 30-yea.r ?eriod beg ;--'- g Ma.y 1 . 1995. a.nd ca.., be eXtended :"ppendix C - 2 ~r2' ~he ~eso~~ces placed i~to the Resource Pool ~ay consis~ c: any c~~bi~ation of resources PacifiCorp owns or ~ay acquire. includi~g. but ~ot l~mited to, thermal generation i~ owns or leases and firm power purchases under contracts with a term of three years or more; provided , that resources placed in the Resource Pool shall only be resources that (1) PacifiCorp acquires through prudent utility management practices and (2) have been declared to be in commercial operation prior to January 1 of the calendar year in which such resources are included in the Resource Pool; provided further, that no resources that utilize fissionable energy sources shall be inc I uded in the Resource Pool. Appendix B - 2 HUNTER # 2 AND # 3 MINE INVES'l'MENTFORMULAS FOR CALCULATINGINITIAL LEVELIZED FIXED CHARGE RATE(Con I ("' 6 )INCOME TAX INCOME TAX (*7)ANNUAL COST ANNUAL COST (Total Return + Book Depreciation + Deferred Tax - Tax Depreciation) x (Tax ratel (I-Taxrate) (55.235+ 57 143 + 52,631 - 514.290) x36811 (1-3681) = 5419 Book Depreciation + Total Return + Interest + Deferred Tax + Income Tax 143 + $5,235 + 54,028 + $2,631 + $419 =519.456 8) TAX DEPRECIATION = (Modified ACRS) x Original InvestmentTAX DEPRECIATION = 14.29% x 1.00 x 5100,000 = $14,290 ("' 9) ITC = Not Applicable ( * 10 ) PRESENT WORTH ANNUAL COST = Annual Cos lI (1 + i ) nPRESENT WORTH ANNUAL COST = 519,456x 1/(1 + .0974)1 =$17,729 where i = weighted cost of capital and n = first year. 11) INITIAL LEVELIZED FIXED CHARGE RATE = (CRF x TotalPresent Worth Annual Cost) ITotal Original Book CostINI7IAL LEVELIZED FIXED CHARGE RATE = (0.13382 xS102.357)/5100,000 = 0.13698 13.698 Appendix A - 21 HUNTER #2 AND #3 M:INE :INVESTMENT CALCULAT:ION OF ADJUSTED :IN:IT:IAL F:IXED CHARGE RATE (Based on SlGO.OOO of Capital Expenditure) CAPITAL STRUCTURE: ComDonen t Structu:-e DebtPreferred Common 50% 10% ' 40% 47% 24% 11.70% Weighted Cost of Capital 74% INPUT DATA: INVESTMENT TAX CREDIT:Not Applicable SALVAGE VALUE: BOOK LIFE (Straigh:Line)yearsTAX LIFE (MACRS)years TAX RATE 37 .77%(inc 1 udes state Corp.tax)TAX BASIS 100.00%of Book PW RATE 74% CALCULATED DATA: CAPITAL RECOVERY FAC~OR = 0.13382 (1 * INITIAL LEVELIZED FIXED CHARGE PATE = 0.13698 = 13.698% (*11) ADJUSTED INITIAL L~VELIZED F:XED CHARGE RATE* = 13.698% less book depreciation. where book depreciation = 1/14 years = 0.07143 =143% = 13.698% - 7.143% = 6.555% BOOK depreciation is reflected in fuel cost. Appendix A - 19 HUNTER #2 PROJECT ALLOCATED MINING EXPENSE CALCULAT:ION (Based on 1990 Actual Costs) Initial ~evelized ;~nual Fixed Charcre Hunter #2 Pro~ec~ Hunter #2 Mining Investment-$26,195,889 Adjusted Initial Levelized Annual Fixed Rate 551% Initial Levelized Annual Fixed Charge $1,716,093 Subsequent Investment Subsequent Levelized Annual Fixed Rate Subsequent Levelized Annual Fixed Charge Ad 'Jalorem Tax Taxes, assessments and in lieu of taxes Administration & General Expenses: 1990 Total PacifiCorp A & G Expense = $145,713,1901990 Total PacifiCorp Electric Plant In Service = 57,884.778.137A & G Expense as a percent of Investment = 1.85%Hunter #2 A & G Expense = 5484.108 Total $2,200.201 - See attached sheet A-16 for details. Appendix A - 1 ANNUAL VARIABLE COST CALCULATION Based on 1990 FERC Form 1 P~o; ec: Annual Load Factors :990 Colstrip L. F.= (951.695 MWh/8760 hrs)/140 MW = 0.78 = 78% 1990 Jim Bridger L. F. = (9.727 673 MWh/8760 hrs)/1333 MW = 0.83 = 83% 1990 Hunter #2 L. F. = (1,772.948 MWh/8760 hrs)/235 MW = 0.86 = 86% 1990 Hunter #3 L. F. = (3.348.751 MWh/8760 hrs)/400 MW = 0.96 = 96% Weiqhted Variable Cost $/MWh = ( (70 MW x 78% x 12.98) + (95 MW x 83% x 14.79) + (235 MW86%12.80) + (400 x 96% x 11.70)) / ((7078%) + (95 MW x 83%) + (235 MW x 86%) + (400 MW x 96%)) $/MWh = 12. Adjusted for Losses:$ /MWh = 12.45/0. Annual Variable Cost:513.10 IMNh Appendix A - 15 Hunter #2 Proj ect Annual Variable Cost (Based c~ 1990 FERC Form Production ~XDenses Operation, Supervision and Engineering Fuel Steam Expenses Electric Expense Misc. Steam Power Expenses Rents Maintenance, Supervision and Engineering Maintenance of Structures Maintenance of Boiler Plant Maintenance of Electric Plant Maintenance of Misc. Steam Plant Sub-Total Allocated Mining Expenses In Lieu of Payments Total Variable Costs Hunter #2 Proj ect Annual Energy Production (~~) Hunter #2 Project Annual Variable Cost . See Attached sheet A-17 for details Appendix A - 13 359,749 14,892,163 255,642 710,564 740,621 874 542,858 367,544 488,547 149,289 (21,706) ---------- $20,486,145 $2,200,201 $22,686,346 772,948 $12.IMWh ------------------ Colstrip Proj ect Annual Variable Cost (Based o~ 1990 FERC Form Colstr:o Pro~ ec:: Annual Energy Production (MWh) Produc:::on Exoenses Opera tion. Supervis ion and Engineering Fuel Stearn Expenses Electric Expenses Misc. Stearn Power Expenses Rents Maintenance. Supervision and Engineering Maintenance of Structures Maintenance of Boiler Plant Maintenance of Electric Plant Maintenance of Misc. Steam Plant Sub-Total In Lieu of Payments. Total Variable Costs Colstrip Project Colstrip proj ect Annual Variable Cost * Montana Electrical Energy License Tax Appendix A - 11 951,695 175,543 481,054 676,840 310,816 032,897 (97,341) 232,610 168,140 462,168 483,955 228,956 --------- $12.155,638 197,102 $12,352,740 $12.98 /MWh f~ling with the FERC :0= a c~ange of rates to reflect any change ~~ the rate of ROE as authorized by the FERC. A4.3 Book DeDreciation Book depreciation charges shall be at a straight-line rate based on a fourteen (14) year life in calculating the initial levelized annual fixed charge rates.Book depreciation charges for subsequent levelized annual fixed charge rates shall be based on the estimated remaining service life of the Project including the effects on such life due to the subsequent investment.Because book depreciation is reflected in the Hunter #2 and #3 fuel cost, an adjustment is made to the initial levelized annual fixed charge rate for the Hunter #2 and #3 project mining investment. pursuant to Subsections A2.1 and A2. A4.Income Tax Reauirements Income Tax Requirements applicable in calculating both initial and subsequent levelized annual fixed charge rates shall be based on the following items: provided. subsequent changes in tax laws shall be incorporated in computing levelized annual :ixed charge rates for periods following such tax law chan~e: A4 . 4 . 1 The federal corporate income tax rate, 46% up through 1986. 40% in 1987 and 34% for the years 1998 through 1992 and 35% in 1993 and thereafter. A4 4 .A state corporate income tax rate equal to the estimated composite weighted average of PacifiCorp I s (3) three-factor formula for unitary allocation of state taxable income based upon payroll, p=operty, and revenue in each state in Appendix A - 9 :ixed c~arge rates and is as :ollows: Long - Term Debt 48% Preferred Stock Common Stock Equity Total 100% orovided , that if any part of PacifiCorp I s portion of the capital additions. replacements. or betterments which occasioned a subsequent levelized annual fixed charge cost is financed by long-term debt. the interest of which is exempt from federal income taxes. the long-term debt portion of the above capital structure shall be apportioned between the long-term debt and the tax exempt long-term debt accordingly.In no case shall the long-term debt portion exceed forty-eight (48%) of total capi talization. A4 2 Cast of CaDital A4.Lana-Term Debt Bond interest applicable in the calculation of each initial levelized annual fixed charge rate will be eight and forty-seven hundredths percent (8.47%).Bond interest applicable ~n the calculation of each subsequent levelized annual fixed charge rate for future capital additions, replacements. or betterments shall be the effective cost rate to PacifiCorp of the most recent issue of long-term bonds, excluding special-purpose issues not related to the Hunter #2 and Hunter #3 Project Mining Investment. in the twelve (12)-month period prior to the date of the completion of construction of the capital additions, replacements or betterments for which the subsequent Appendix A - 7 if any), and betterments of ~~e Hunter #3 proj ect allocated mining investment, completed d~=~~g the calendar year imrnediacely preceding establishment of such subsequent levelized annual fixed charge.Such dollar investment, to be determined from data contain in PacifiCorp's FERC Form 1 or its successor chereto, shall not include any dollar amounts incurred by PacifiCorp prior to January 1, 1991. A2.All ad valorem taxes imposed upon the Hunter Project mining investment. A2.Administrative and General Expense shall be an amount equal to the product of 1) the quotient of total PacifiCorp administrative and general expenses to total PacifiCorp electric plant in service; and 2) the total Hunter #3 Project mining inves tmen t Section A3:Alloca of Minina In tmen ter 2 and Hunter Pro; ects Hunter #2 mining initial investment and Hunter #3 mining ini tial ~nvestment shall be determined by (a) multiplying the dollar amount as set forth in Section A3.1 by (b) the ratio of PacifiCorp's share of the associated proj ect I s capability (235 MW for Hunter #2 proj ect and 400 MW for Hunter #3 Proj ect)divided by the total capability of all Projects served by the mines (presently 1995 MW) Hunter #2 mining subsequent investment and Hunter #3 mining subsequent investment shall be determined by (a) multiplying the dollar amounts as set forth in Section A3. 2 by (b) Appendix A - 5 deter~mined pursuan~ to Section A3. as of December 31, ~990.=or purposes c: ~his section. ?aci:iCorp' s total investment in Hunter #2 projec~ ~ining is 526.195.389.Such total investment shal: remain constant ~trough the book life (14 years) and shall be SO afterwards.Such adjusted initial levelized annual fixed charge rate shall be determined by subtracting book depreciation (l/book life) from PacifiCorp I s initial 1evelized annual fixed c~arge rate for the Hunter #2 project mining investment determined annually in accordance wi th Section A4. below.Such book depreciation is reflected in Hunter #2 fuel cost. A2.The sum of all subsequent annual levelized fixed charges, each of which shall be determined by multiplying (a) Paci:iCorp I s subsequent levelized annual fixed charge rate for each year, for the Hunter #2 proj ect mining investment, as calculated in accordance with Section A4, below, by (b) the dollar investment in capital additions. replacements (less credit for net salvage and insurance proceeds. if any), and betterments of the Hunter =2 Project allocated mining investment, completed during the calendar year immediately preceding establishment of such subsequent levelized annual fixed charge.Such dollar investment, to be determined from data contain in PacifiCorp' s FERC Form 1 or its successor thereto, shall not include any dollar amounts incurred by , PacifiCorp prior to January 1, 1991. A2.All ad valorem taxes imposed upon the Hunter #2 Project ~ining investment. A2.Administrative and General Expense shall be an Appendix A - APPENDIX A ANNUAL VARIABLE COST This Appendix sets forth the elements and tecr~iques to calculate the Annual Variable Cost. tion Determination of Annual Variable Cost The Annual Variable Cost shall be the $/MWh result of the following:(1) the product of 70 MW multiplied by the Colstrip annual load factor multiplied by the Colstrip Project nnnual Variable Cost plus the product of 95 MW multiplied by the Jim Bridger annual load factor multiplied by the Jim Bridger proj ect Annual Variable Cost plus the product of 235 MW multiplied by the Hunter #2 annual load factor multiplied by the Hunter #2 Project Annual Variable Cost plus the product of 400 MW multiplied by the Hunter #3 annual load factor multiplied by the Hunter Proj ect Annual Variable Cost.( 2) dividing the above sum by the ~otal of 70 MW multiplied by the Colstrip annual load factor plus 95 MW multiplied by the uim Bridger annual load factor plus 235 multiplied by the Hunter #2 annual load factor plus 400 MW multiplied by the Hunter #3 annual load factor, and (3) dividing the above ratio by 0.95 which represents the adjustment factor for transmission losses. Appendix A (a)To any person or entity into which or with which the Party making the assignment is merged or consolidated or to which the Party transfers substantially all of its assets; (b)To any person or entity wholly owning, wholly owned by, or wholly owned in common with the Party making the assignment; (c)The Redding Joint Powers Financing Authority. Nothing contained in this Section shall be construed to prevent PacifiCorp from making a collateral assignment of the revenues due under the terms of this Agreement.No assignment, merger or consolidation shall relieve any Party of any obligation under this Agreement.Subj ect to the foregoing restrictions in this Section 21, this Agreement shall be binding upon, inure to the benefit of, and be enforceable by the Parties and their respective successors and assigns. Page 34 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING preserve the original intent contemplated by the Parties. the event the Parties are unable to renegotiate the terms and conditions of this Agreement, this Agreement shall terminate within 60 days of receiving notification from FERC, any agency, or any court of competent jurisdiction requiring material modifications to this Agreement. 17.Waixer Any waiver by a Party to this Agreement of its rights with respect to a default hereunder, or with respect to any other matter arising in connection herewith, shall not be deemed to be a waiver wi th respect to any subsequent default or matter. No delay,short of the statutory period of limitations, asserting or enf orc ing any right hereunder shall be deemed waiver of such right. 18.Indemnification Neither Party (First Party), shall be liable whether in warranty, tort, or strict liability, to the other Party (Second Party) for any injury or death to any person, or for any loss or damage to any property, caused by or arising out of any electric disturbance on the First Party's electric system, whether or not such electric disturbance resulted from the First Party's negligent act or omission.Each Second Party releases the First Party from, and shall indemnify and hold Page 32 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING any such audit discloses that an overpayment or an underpayment has been made, the amount of such overpayment or underpayment shall promptly be paid to the Party to whom it is owed by the other Party plus interest at the prime rate as defined pursuant to Appendix 13.PacifiCorc's Audit Riahts PacifiCorp, at its expense, shall have the right to audit and examine any document in Redding I s possession related to the condition or operating performance of San Juan.Any such audit shall be undertaken by PacifiCorp or its representatives at reasonable times and with reasonable prior notice. 14.Notices All written notices, demands or requests required by the Agreement or the provisions hereunder, including billing invoices, shall be considered given when delivered in person, or prepaid telegram, or sent by first class mail, postage prepaid deposited in the U.S. Mail, directed as follows: Page 29 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING interest calculated at the prime rate as defined pursuant to Appendix F. 11. 3 Billi~o and PaYment Schedules PacifiCorp shall bill Redding each month by certified mail for Firm Capacity and Firm Energy provided during the preceding month.Redding shall pay such amounts wi thin 30 days of receipt of such bill. Payments for all services provided hereunder are to be made by means of an electronic wire transfer to the following: (Electronic Wire) Attention: Cash AdministratorUnited States National Bank of Metropolitan Branch 900 S. W. Sixth AvenuePortland, OR 97204 Oregon (For credit to PacifiCorp, Account No. 070-0000-169, A.A. No. 123000220) Payments not received within such 30-day period shall be considered overdue.Beginning with the 31st day, overdue bills shall have added to them an initial charge of two percent (2\) of the amount unpaid.Each day thereafter, a charge of five hundredths percent (.05%) of the principal sum unpaid shall be added until the amount due , including the two percent (2t) initial charge, is paid in full.Payments received will first be applied to the charges for late payment assessed on the principal and then to payment of the principal.OVerdue charges consisting of the initial charge of two percent (2t) and the daily charge of five hundredths (0.05\) will not exceed the highest rate allowed under applicable law. Page 27 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING precedence over deliveries which use the same transmission resources as deliveries under this Agreement and which occur under agreements which are entered into by Redding after the date of this Agreement. 10.Short-Fall Enerav During the Exchange Period, energy deliveries associated with curtailments pursuant to Sections 10.1 and 10.2 that result in schedules of Exchange Energy below 20 megawatt-hours per hour shall be deemed Short - Fall Energy. 11.Billing 11.1 Firm Cacacitv and Enerav Pavments Redding shall pay PacifiCorp each month of each Contract Year during which Firm Capacity and Firm Energy is made available to Redding as follows:The payment each month for Firm Capacity and Firm Energy deliveries pursuant to Sections 6 and 7 respectively, shall equal the sum of:(1) the price specified in Section 8. multiplied by SO megawatts and (2) the Estimated Annual Variable Cost (expressed in dollars per megawatt-hour) multiplied by the amount of Firm Energy delivered (or required to be purchased, whichever is greater), during such month pursuant to Section 7 (expressed in megawatt-hours) with such amount being adjusted by the credit or the payment for Undelivered Power pursuant to Section 8. Page 2S - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING typical weekday Saturday and Sunday/holiday hour-by-hour schedule.Prior to 0750 hours Pacific Time each work day, PacifiCorp shall furnish a preschedule for the following day (s) showing the intended hourly schedule of San Juan energy. Redding shall make best efforts to notify PacifiCorp of any change necessary in prescheduled quantities necessitated by an operating emergency or outage and the expected duration of the operating emergency or outage.PacifiCorp shall make best efforts to notify Redding of any changes necessary in prescheduled quantities due to emergencies on its system. Real-time schedule changes should be reported to Redding at least 45 minutes prior to the affected hourly scheduling period and, preferably 60 minutes prior to the affected hourly scheduling period. 10.Svstem Loas All deliveries hereunder shall be deemed to be made during the hours and in the amounts as accounted for in Redding I s and PacifiCorp I s dispatchers I system logs; provided, that if scheduled deliveries are interrupted due to an Uncontrollable Force as defined in Section 15 such schedules shall be adjusted to reflect such interruption. the event of such interruption Redding I s schedule will be reduced on a pro rata share basis with PacifiCorp I s other firm off-system wholesale sale obligations affected by such Uncontrollable Force. Page 23 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING 10.Schedulinq of Additional Enerav bv Reddinq Redding has elected the Additional Energy delivery option set forth in Section 9.7(a), the Maximum Hourly Rate of Delivery (stated in megawatt-hours and rounded to the nearest whole megawatt-hour) shall equal the result of the following equation: = Maximum Hourly Rate of Delivery310 Off-Peak Hours Where: A Total Additional Energy Available toRedding (megawatt -hours) Provided, however, the Maximum Hourly Rate of Delivery of Additional Energy shall in no event be greater than 50 megawatt-hours per hour and PacifiCorp shall not be obligated to accept schedules of less than 5 megawatt-hours per hour. If Redding has elected the Additional Energy delivery option set forth in Section 9.7 (a), the Maximum Monthly Delivery shall equal the product of the Maximum Hourly Rate of Delivery, calculated above, multiplied by 265 (rounded to the nearest whole megawatt-hour) If Redding has elected the Additional Energy delivery option set forth in Section 9.7 (b), the Maximum Monthly Schedule of Additional Energy (stated in megawatt-hours and rounded to the nearest whole megawatt-hour) shall equal the total amount of available Additional Energy, not to exceed 10,300 megawatt-hours. Page 21 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING such San Juan Alternate Power at the highest rate PacifiCorp is then permitted to charge pursuant to PacifiCorp 's FERC Electric Tariff, Second Revised Volume 3, or its successor tariff of general applicability.Purchases under such Tariff shall continue for a minimum of 12 consecutive months.Thereafter, Redding shall again be permitted to procure San Juan Alternate Power subj ect to Pacif iCorp I s right -of - first -refusal. 2 .2. 9 Power Exchanqe Examcles Appendix ~ sets forth examples of Exchange Energy. Bond Covenant Restriction (s) PacifiCorp hereby acknowledges that federal tax law imposes certain restrictions regarding the terms and conditions under which Redding is permitted to deliver San Juan energy to PacifiCorp without adversely affecting the tax-exempt status of the bonds issued by M-S-R to finance its share of the facilities comprising the San Juan generating station. PacifiCorp hereby represents and covenants that to the extent any energy exchanged by Redding under this Agreement is exchanged on a nonsimultaneous basis, PacifiCorp shall use such energy for the pUrpose of satisfying one or more of PacifiCorp I S peak demands.Redding and PacifiCorp agree that one manner in which the latter may satisfy the foregoing covenant is by using San Juan energy in place of hydroelectric energy to meet its then-current load and thereby continue storing water "behind the dam" for purposes of meeting Page 19 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING adjusced by:(a) multiplying them by a fraction whose numera~or is the hourly amount of energy available pursuant to the Maximum Enti:lement following the rerating (stated in megawatt-hours) and whose denominator is 21.5 and (b) rounding the result to the nearest whole megawatt-hour) . Additional Eneray Winter Energy accumulated during any Contract Year (if any), Short-Fall Energy accumulated during such Contract Year (if any), and any unscheduled Seasonal Energy during such Contract Year shall collectively be deemed II Additional Energy;" provided, however, that any amounts of Seasonal Energy accumulated during the month of November of a Contract Year and any amounts of Additional Energy accumulated during the Season and November of such Contract Year may be carried forward to the following Contract Year. Reddina's Additional Enerav Deliverv O'Ot ions Redding shall have two options for taking delivery of Additional Energy; provided that only one of these options shall apply during any Contracc Year. follows: These options are as ( a)Subj ect to the provisions of Section 10. Redding may take delivery of any accumulated Additional Energy : (i) on a firm basis during the months of March, April and November during Off-Peak Hours and Page 17 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEENPACIFICORP AND CITY OF REDDING delivery of 130,000 megawact-hours.During every hour that Unit 4 available capacity is reduced for other than planned annual maintenance outages, such annual obligation shall be decreased by the difference between 21.5 megawatt-hours per hour and such reduced available capacity. Additional Deliverv Riahts addition to the rights and obligations set forth in Section 3 of this Agreement, PacifiCorp shall have the right to take delivery of Power and the obligations to make Power available under the reserve sharing terms of Appendix D to this Agreement. Schedulina Arranaements PacifiCorp shall make the necessary scheduling arrangements to take delivery of San Juan Power at the Point (s) of Delivery for the term of this Agreement and Redding I s obligation to schedule such Power beyond the Point (s) of Delivery shall be accordingly eliminaced. PacifiCorc Deliveries to Reddina During each Season, subject to the availability of accumulated and remaining Seasonal Energy, PacifiCorp I s obligation to deliver Power to Redding, and Redding I s obligation to take delivery of Power, shall be as follows: Maximum Cacacitv Deliverv PacifiCorp shall make available to Redding at the Point of Delivery SO megawatts of capacity. Page 15 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING adjustment is a positive number, such amount shall be subtracted from Redding I s bill for such month. Exchanqes of Power Amendments to Oriqinal Aqreement and Exchanqe Aqreement 1.1 Oriqinal Aqreement The Original Agreement shall be he reby Section shall be hereby amended by deleting the existing provisions of Exchanqe Aqreement The Exchange Agreement amended by deleting the existing provisions of Sections 5.1, 5.3 and 5.4 thereof and substituting a new Section 5.1, which provides as follows: Effective Date and Termination This Agreement shall become effective upon execution by both Parties. Service underthis Agreement shall commence at the hour ending 0100 Pacific Time on May 1, 1995 andshall terminate at the hour ending 2400 Pacific Time on November 30, 2000. Seasonal Exchanqe During the Exchange Period, Redding and PacifiCorp shall exchange Power as follows: Reddinq Deliveries to PacifiCorp During each month of the Exchange Period, Redding I s obligation to deliver Power to PacifiCorp shall be as follows: Maximum San Juan Power Delivery Redding shall make available to PacifiCorp at the Point of Delivery its maximum share of capacity from San Juan through a Page 13 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Prices Redding shall be obligated to pay PacifiCorp for all Firm Capacity and Firm Energy as follows: Firm CaDacity The price for Firm Capacity shall be $1,000 per megawatt-month. Firm Enerav The price for Firm Energy shall be the Annual Variable Cost. Estimated Annual Variable Cost Beginning on March 15, 1996, and on or before each September 15 thereafter, PacifiCorp shall provide to Redding the Estimated Annual Variable Cost which will be applicable for billing purposes during the following partial or whole Contract Year, whichever is applicable, in order for payments to be made on a monthly basis pursuant to Section 11.Such estimates shall be determined utilizing the best information then available to PacifiCorp.PacifiCorp shall provide, at Redding's request, appropriate work papers and documentation supporting the determination of the estimates.If, at any time during any Contract Year, PacifiCorp determines that the Estimated Annual Variable Cost used for billing purposes during the Contract Year should be adjusted to reflect more accurate estimates, PacifiCorp shall notify and supply supporting documentation to Redding as soon as possible and shall revise the Estimated Annual Variable Cost.Said revised estimates shall be used for Page 11 - LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING with the FERC a letter supporting PacifiCorp I s filing of this Agreement.If the FERC does not accept this Agreement for filing in its entirety, the Parties shall exercise best efforts to amend the Agreement pursuant to Section 16 to comply with the FERC action in a manner consistent with the Parties' original intent.In the event such amendment is not executed by the Parties within 60 days, or longer if the Parties mutually agree to an extension, following the FERC's action, PacifiCorp shall withdraw its filing with the FERC and this Agreement shall terminate.In any event, if the FERC does not accept this Agreement for filing on or before May 31, 1996, this Agreement shall terminate. Firm CaDaci tv Provisions Base Amount Except as provided for in Section 6. beginning on the Service Commencement Date and continuing through November 30, 2000, PacifiCorp shall make available at the Point of Delivery, and Redding shall purchase, SO megawatts of Firm Capacity each month. ODtion to Reduce If Redding experiences an identifiable loss of firm load, Redding' 5 Firm Capacity obligation may be reduced by the amount of loss, to the nearest whole megawatt ("MW"), not to exceed the following limits: Page 9 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING by the Parties I schedulers and dispatchers such that no additional costs are incurred by the Parties.Point of Delivery" means for all deliveries of Exchange Energy from PacifiCorp to Redding hereunder, COB, or other points as mutually agreed upon by the Parties I schedulers and dispatchers.Point of Delivery" means, for all deliveries of capacity and energy from San Juan hereunder to PacifiCorp, at the election of PacifiCorp for any hour, Palo Verde, Westwing, Moenkopi or, subject to Appendix C of this Agreement, San Juan, or other points as mutually agreed upon by the Parties schedulers and dispatchers. Power" means electrical capacity and associated energy . San Juan Alternate Power" means a power resource that is substantially similar in quality and power output characteristics to the resource made available to PacifiCorp by Redding pursuant to Section 9. Season" means each period of May 1 through October 31 during the Exchange Period. Seasonal Energy" means energy available to Redding equal to the amount of energy from San Juan that PacifiCorp has scheduled during the Contract Year in which the Season occurs (to the extent PacifiCorp I s monthly schedules have not exceeded 12, 000 megawatt-hours in any month) but not to exceed the annual minimum delivery obligation pursuant to Section 9. Page 7 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING added to the Resource Pool pursuant to Appendix B, being determined by a methodology substantially similar to that set forth in Appendix A. between the States of California and Oregon on the 500 kV California-Oregon Border" ("COB") means the boundary transmission lines known as the Pacific Northwest/Pacific Southwest A. C. Intertie where transactions between electric systems commonly occur. Contract Year" means, during the term of this Agreement, a continuous 12 -month period beginning each December 1 of each calendar year and ending November 30 of the following calendar year. estimate of the Annual Variable Cost, based on the best Estimated Annual Variable Cost" means PacifiCorp I information available to PacifiCorp at the time such estimates are made pursuant to Section 8.3, to be used for billing purposes under Section 11. Agreement between PacifiCorp and Redding dated April 25, 1995. Exchange Agreement" means the Power Exchange Redding by Pacif iCorp pursuant to Section 9. Exchange Energy" means energy made available to 2000 through the balance of the term of this Agreement. Exchange Period" means the period of December 4 . available to Redding from PacifiCorp I s total system resources. Firm Capacity" means system capacity that is made Page 5 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING M-S-R has a 28.8 percent (143 megawatts) ownership interest in Unit 4 of the San Juan coal-fired power project in northwestern New Mexico (" San Juan" ) . M-S-R and Tucson Electric Power Company ("TEP") executed an interconnection agreement ("TEP Interconnection Agreement ") dated September 20, 1982.Service Schedule E (dated January 23, 1985, appended as Appendix D to this Agreement) to the TEP Interconnection Agreement sets forth terms and conditions under which TEP and M-S-R share the reserve capacity and the reserve liability associated with and occasioned by their respective ownership interests in San Juan Units 1, 2 and Among other things, the TEP Interconnection Agreement provides M-S-R with reserve-sharing rights and obligations. Redding has a 15 percent entitlement in M-S-R I rights to Power from the San Juan proj ect and rights under the TEP Interconnection Agreement. On April 25, 1995, Redding and PacifiCorp entered into a Power Exchange Agreement (" Exchange Agreement") pursuant to which Redding exchanges its share of San Juan Unit 4 capacity and associated energy, as enhanced by the TEP Interconnection Agreement, to PacifiCorp in exchange for capacity and associated energy provided by PacifiCorp to Redding. Page 3 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING Preamble THIS POWER SALE AND EXCHANGE AGREEMENT (" Agreemenc"), dated this 6th day of December 1995 is becween PacifiCorp, an Oregon corporacion (" PacifiCorp"), and the City of Redding, a municipal corporation organized under the laws of the State of California ("Redding"Redding and PacifiCorp are somecimes herein referred to collectively as .. Parties" and individually as .. Party. Exclanatorv Recitals PacifiCorp and Redding are both engaged in the generacion, transmission and discribUCion of eleccric power and energy . Redding desires to purchase long-term capacity and energy from PacifiCorp under the terms and conditions of this Agreemenc . PacifiCorp desires to sell long-cerm capacity and energy to Redding under the terms and conditions of this Agreement. On October 19, 1993, Redding and PacifiCorp entered into a "Long Term Power Sales Agreement between PacifiCorp and Page 1 -LONG-TERM POWER SALE AND EXCHANGE AGREEMENT BETWEEN PACIFICORP AND CITY OF REDDING LONG - TERM POWER SALE AND EXCHANGE BETWEEN PACIFICORP AND CITY OF REDDING AGREEMENT Index to Sections Section preamble Explanatory Recitals Agreement Definitions Term and Termination Firm Capacity Provisions Firm Energy Delivery Provisions Prices Exchanges of Power Scheduling Billing Cost Determination Changes AUdit Rights Notices Uncontrollable Forces Regulatory Impact Waiver Indemnification Dispute Resolution Amendments Assignability Page 'l , . :.. ~ '7: ~'; jo,. ;.. ,?" ~... :.,.; ~, ".- '~- :h.. ,?\.. ~' . .- jo,. ,~. ..... I1=IY-04-2000 13:29 1f!NSPL T~103 267 6906. .rr-u- . - .... Confuma.tJon Agreement P. 21/23 POD Descriptions . - " ALVEY 500 kV POINT OF DELIVERY Location: the point in BP A's Alvey Substation where the 500 kV facilities of the Parties hereto arc connected; Voltage: 500 tV; Metering: in BP A's Alvey Substation, in the 500 tV circuits over which elCcuic power and energy flows; FAlRVIEW 230 kV POINT OF DELIVERY LocaDon: the point in BP A '5 Fairview Substation where the 230 tV facilities of the Parties hereto are COMected; Voltage: 230 tV; Meterinl: in BPA's Fairview Substation, in the 230 leV circuit over which electric power and energy flows; McNARY 230 kV POINT OF DELIVERY Location: the point in BP A 's McNary Substation where the 230 tV facilities of the Parties hereto are connected; Volta8e: 230 tV; MeWing: in BP A's McNary Substation, in the 230 kV circuit over which electric power and energy flows: . '~ , . -.. -, MIDWAY POINT OF DELIYERY Location: the point in BPA's Midway Substation where the 230 kV facilities of the Parties hereto are connected; . , '1 ;: Voltage: 230 tV; Metering: in BP A 's Midway Substation. in the 230 k V circuit over which electric power and energy floW$; MAY-04-2000 13: ~I=t.. T~41113 267 691216 19/2::: The deratings in the following table ere arranged in order of priority - from most urgent to least urgent The add screen In the AIS system will only accept these standardized NERC event types. Event Description of Deratings - Restrictions Type cla ed (Forc tin mediate - A derating that requires an immediate reduction In capacitY. ned rced)tin ved - A derating that does not require an D2%immed'l8te reduction in capacity but requires a reduction in capacity within six (6) hOUTS. lanned (orc ratin - Pos ed - A derating that can be postponed beyond six hours but requires a reduction in capacity before the end of the next weekend. Maintenan erstin - A derating that be deferred beyond the end of the next . weekend but requires 8 reduction in capacity before the next Planned Outage (PO). A 04 can have a flexible stan date and mayor may not have a predetennined duration. Plan d De - A derating that is scheduled well in advance and Is of a predetennined duration. (Periodic derating for tests, 8uch as weekly turbIne valve tests, should not be reported as PO's. Repon deratings 1or these types as Maintenance Oeratinos lD4t . ~ '\, ~~ ,. ' 2 These event types are all contributors to the EFOR calculations In the reports section. MAY-04-2000 13: 28 !=N51=t.. TA '03 267 691116 17/23 Appendix B - Event Types The outages In the following table are arranged in order of priority. from most urgent to least urgent. The add screen in the AIS system will only accept these standardized NERC event typBB. Event D~scription of Outages Type nned ) Outa e - Imm diate - An outage that requires Immediate removal of a unit from service. another outage state or a Reserve Shutdown state. This type of outage'results from Immediate mechanicaVelectrica\lhydraufic control svstems trips and ocerator.initiated triDs In response to unit alarms. lanned Forced) Outa - Delayed - An outage that does not require Immediate removal of a unit frem the in.servlce state but requires removal within six (6) hours. This tvDe of outaQe can onlY occur while the unit is in service. . Un ed rced\ Outa . PostPoned. An outage that oan be poStpOned beyond six hours but requires that a unit be removed from the in-service state before the end of the next weekend. This type of outage can only occur whne the unit is in service. arN FaDure . An outage that results from the inability to synchronize a unit within a specified startup time period following an outage or Reserve Shutdown. A startup SFI period begins with the command to start and ends when the unit Is synchronized. An SF begins when the problem preventing the unit from synchronlz:ing occurs. The SF ends when the unit is svnchronized or another SF OCCUIS. ntena ce Outaae . An outag~ that can be deferred beyond the end of the next weekend. but requires that the unit be removed from service before the next planned outage. (Characteristically. 8 Me can occur any time during the year, has a flexible start date. may or may not have a predetermined duration encl. usually much shorter than a PO. ~alntena e Out extension - An extension of e maintenance outage (MO) beyond Its estimated completion date. This is typically used where the original scope of work requires more time to complete than originally scheduled. Do not use this where unexpected problems or delays render the unh out of servioe beyond U'Mt estimated end date of the MO. Pla d Outa e . An outage that Is scheduled well in advance and is of a predetenninecl duration. lasts for several weeks and occurs only once or twice B year. (Boiler overhauls. turbine overhauls or Inspections are typ1cal p1anned outseel. ed Outa xtension - An extension of a planned outage (PO) beyond Its estimated completion data. 'This is typically used where the orlglr1al scope ofwark requires more time to complete than originally scheduled. Do not use this where unexpected problems or delays render the unit out of service beyond the estimated end date of the PO. , ~ '\..... I These event types are aU oontributors to the FOR & EFOR calculations In the reports &ectlon. 05/03/00 WED 10: 10 FAX 503 81~PaclflCorp Jfthe above reflects your underst3nding oftbe agreement reached between the repre.sent:ltive$~f cur o!"s2ci3:U.icn&,.ple.:!.s9~i-gn,~~te; one :~tu:n on~ r..ul'j"'ox(!CU~ ~j' ....., of this Confirmation Agreement. Sincerely, TRANSALTA ENERGY MARKETING (U.) INe. By. Name: 152.",,-, v.. C'LI?v..I~ ~O05 Title: A uTtk)-\! Z8") ftiLS:U,:J Date:rf\ A- '-1 - w-. z.. 0-0 By::Fj) ,__ Name: e If) br:- r- i)L,".. I k.. Tit1!::(~ rJ (' rti NjJ Date: . y / )'0~ Date: . " "L. " .:..'~ .. . - " MAY-04-2000 13:27 1~1=L TA'11a3 267 691216 P. 13/23 records and supporting documents and agree on any adjustments that may be appropriate. If the panies agree that the billing is incoITect. a corrected bill shall be p~pared and the difference between the incorrect bill and corrected bin, including interest at shall be paid promptly after such detcnnination. Neither Party shan und~rtake an audit a.o;sociated with billings 36~months months or older. The principal upon which interest rates are to be applied shan be limited to the difference between the inconect bill and con-ected bill for the 36-month period preceding the point in time that the issue was raised. PacifiCorp shan take all steps rusonably available to secure the confidentiality of TEMUS.s accounting records and supporting documents. Djsc1osure otaccounting records and supporrlng documents to PadfiCorp is not intended to, and shall not be interpreted to, waive TEMUS'$ right to deem that such records and supporting documents are privileged. confidential, proprietary. or otherwise protected from disclosure to the public. In the event such information is required in a legal or regulatory proceeding related to tbjs Confirmation Agreement, PacifiCorp shall advise TEMUS of the requirement to disclose such information prior to disClosjng it and, at TEMUS's request, shall ask for confidentiality of any such information. Sccti9n 17 - Assignment Neither Party may assign their rights under this Confirmation Agreement without the consent of the other Party, whjch consent shall not be unreasonably withheld; provided.the non-assigning Party may feqUire additional credit related assurances which may include. but shall not be limited to, an mevocable lener of credit in a fonn, amount and nom a fmancial institution acceptable to the non-assigning Party. Section 18 - Choice of Law To the extent that the performance, construction, interpretation OT adminiStration of this Confmnation Agreement is subject to State law, this Agreement shan be subject to the laws of the State of Washington. ,. , Se.cti9n 19 - Captions and Constnlction . . .. " ' 19.All indexes, titles, subject headings, section titles, and similar items are provjded for the purpose of refa-encc and convenience and are not intended to affect the meaning of the content Of scope of this Confirmation Agreement. 19.2 Every tenD and provision of this Confirmation Agreement shall be construed simply according to its fair meaning and not strictly for or against any Party. Section 20 - Partial Invalidity If any of the terms of this Confmnation Agreement are finally held or detennined to be invalid, illegal or void, all other tenDS of this Confirmation Agreement shall remain in effect If any terms are finally held or detennincd to be invalid, illegal or void, the Parties shall enter into negotiations concerning the terms affected by such decision for the purpose of achieving conformity with requirements of any applicab1c law and the intent MAY-04-2000 13: 26 (~AL TA 103 267 691216 11/23 and as neceSsary to fulfill the total monthly obligations of both Parties pursuant to Section Section 11 - Tvoe of Service An schedules pursuant to Section 10 for delivery to the Mid-Columbia shall be firm as defined by the WSPP Agreement for Schedule C2 (as amended or replaced) transactions. All schedules pursuant to Section 10 for delivery to Paul shan be fInD for the hour of delivery as defined by the WSPP Agreement for Schedule C2 (as amended or replaced) transactions; provided. the Parties shall implement the provisions of Section 10.4 in the cvcnt of a Forced Outage or CunailmenL Unless otherwise mutUally agreed, TEMUS shall be responsible for providing all within hour reserves associated with all deliveries m~ under this Confirmation Agreement. Section 12 - Billin~ and Pavrncnt 12.1. All billings and payments associated with this Confirmation Agreement shal1 be in accordance with Section 9 of the WSPP Agreement and the Netting Agreement: provi~TEMUS shan prepare PacifiCorp s bill each month for amounts associated with Section 7.2 by; (1) utilizing the volume weighted (utilizing actUaJ energy deliveries during On-Peale and Off-Peak bours during the billing month) average of the On-Peak Index and Off-Peak Ind~x for the billing month. minus (2) the Adjustment with (3) the application of the Ceiling and Floor as listed in Table B. At the end of each calendar quarter. the previous two monthly billings shall be reconciled to account for the fact that the Ceilings and Floors are. intended to apply on a quarterly basis as per the example ca1culation included in Appendix C. To the extent there are adjustments necessary due to such quarterly reconci1iation, any monthly amounts owed by one Party the other Party shall be adjusted for Prime from the date TEMUS received such monthly payment from PacifiCorp to the date of receipt by PaeifiCorp for the monthly invoice that contains such reconciliation. . , . 12.TEMUS shall transmit monthly invoices to PacifiCoII' via facsimile and by regular postal service mail or by any such other means the Parties mutUally agree upon in writing. 12.3 In the event of a conflict between the Netting Agreement. the WSPP Agreement, or the Confmnauon Agreement, any such conflict shall be resolved by reference to the tenns contained in such agreements in descending order of importance as follows: this Confmnation Agreement, the Netting Asreemcnt, the WSPP Agreement. Section 13 - Liquidated Dama~ In the event TEMUS fails to meet its minimum delivery obligation hereunder, or. PacifiCorp fails to take receipt of any deliveries, as provided for herein, the liquidated damages contained in Section 21.3 of the WSPP Agreemcnt shall govern. PacifiCorp shall operate its electrical system pursuant to Prodent ElectricaJ Industry Practice. TEMUS shall assure that Centralia is operated pursuant to Prudent Electrical Industry MAY-04-2000 13:25 ~I=L TA '13 267 691116 09/23 TEMUS shall pre-schedule 300 MWlhour to PacifiCorp at Paul, unless modified pursuant to Sections 10.5 or 10., for the time period June 1,2001 through June 3D, 2002, by 0900 bours PPT on the mutually recognized pre-scheduling business day prior to the day(s) of delivery; provided, TEMUS shall be able to reduce such scheduled amountS no later than 30-minuteS prior to the hour of delivery in the event of a Forced Outage or Curtailment; m:ovided funber, TEMUS shall have the obligation to increase any such reduced scheduled amounts, by giving Pac)fiCorp notice no later than 3D-minutes prior to the hour of delivery, when the event of Forced Outage or any portion of a Curtailment event ends unless deli "cries are taking place pursuant to Section 10.4 in which case deliveries shall resume at HE 01 00 on the day immediately following the day that scbedules pursuant to Section 10.4 end. 10.To the extent Ccntralia is A vailablc, or anticipated to be A vaiJable, TEMUS shall schedule 400 MW /hour to PacifiCorp at Paul, unless modified pursuant to Sections 10.5 or 10.6, for the time period July I, 2002 through June 30, 2007, by 0900 hours PPT on the mutually recognized pre-scheduling business day prior to the day(s) of d~1ivery; provided, TEMUS shall be able to reduce such scheduled amounts no later than 3D-minutes prior to the hour of delivery in the:. event of a Forced Outage or Curtailment; provided further.TEMUS shall have the obligation to increase any such reduced scheduled amounts, by giving PacifiCorp notice no later than 30-minutcs prior to the hour of delivery, when the event of Forced Outage or any portion of a Curtailment event ends unless deliveries arc taking place pursuant to Section 10.4 in which case deliveries shall resume at HE 01 00 on the day immediately following tbe day that schedules pursuant to Section 10.4 end. 10.TEMUS shall have the obligation to schedule and deliver a nrlnimum amount of energy each month to PacifiCorp, pursuant to the terms of Sections 10.1, 10. 10.4. 10.5, and 10.6, equal to; (1) the hourly amounts provided in the applicable Sections 10.1 or 10.2 multiplied by (2) the number of bours in the applicable month multiplied by (3) 0.94. 't-L .;'"" .. ..:.. ~~ ~~' ' 10.Upon the occurrenCe of a Plant .Contingency, TBMUS s1i~~1 IC~jse its Paul delivery schedule pursuant to the terms of the applicable Section 10.1 or 10.2. For the duration of the plant Contingency, TEMUS shall have the right to make deliveries to PacifiCorp at Mid-Columbia as described in this Section 1 0.TEMUS shall be obligated to provide PacifiCorp s pre-schedulers, by the later of 0700 hours PPT following the Plant Contingency or hours following the Plant Contingency, with the expected duration of the Plant Contingency and the delivery day and delivery amounts that TEMUS intends to schedule to PacifiCorp at Mid-Columbia; provided.41DY Mid- Columbia deliveries scheduled pursuant to this Section 10.4, unless TEMUS schedules in rca1-time pursuant to Section 10.1, shall be pre-scheduled by 0700 hours PPT on the mutually recognized scheduling day prior to the day(s) of delivery; provided further, such Mid-Columbia schedules shall be in twenty four equal hourly amounts as deterII1ined by the diff~rence between the hourly amounts pursuant to Sections 10.1 or 10.2, as applicable (unless modified pursuant to Sections 10.or 10.6) and the reduced hourly schedule at Paul doe to th~ Plant Contingency. TEMUS shall have the obligation to continu~ such Mid-Columbia schedules through the tonger of the duration of the Plant ~ ':"'; ', .,-* NsI=L TA ''13 267 6906 B71'23 2004 22. 2004 44. 2004 34. 2005 29. 2005 22. 2005 45. 2OOS 34.58 2006 30.16 2006 22. 2006 45. 2006 34. 2007 30. 2007 22. MAY-04-2000 13:25 For the time period June 1,2001 through June 30.2002, PacifiCorp shall pay TEMUS each month, associated with (1501300)% of the energy delivered and received each month; (l)lhe energy rate equal to the volume weighted (utilizing actus) energy deliveries during On-Peak and Off-Peak hours during the calendar quarter) average of the On-Peak Index and Off-Peak Index for the calendar quancr in which the billing month faUs, minus (2) the Adjustment with (3) the application of the Ceiling and Floor as listed in Table B below. For the tUne period July 1. 2002 through June 30. 2Off1. PacifiCorp shall pay TEMUS each month. associated with (150/400)% of the energy delivered and received each month; (1) the energy rate equal to the volume weighted (uti1izing actual energy deliveries during On-Peak and Off-Peak hours during the calendar quarter) average of the On-Peak Index and Off~Peak Index for the calendar quarter in which the billing month falls. minus (2) the AdjUstment with (3) the application of the CeHing and Floor as listed in Table B be1ow. An example calculation is included in , ~ . :ApPFndlx A. , " , . r . , uarter Janu March Year 2001 53.30.1.25 2001 47.25.1.50 2002 43.56 22.50 2002 37.14. 2002 60.36.1.50 2002 49.26.1-'0 2003 43.22.1.50 MI=IY-04-2000 13:24 NSAL TA '3 267 6906 P. BS/23 amOUr)ts on a pro-rata basis for the appl1C8bl~ hour. A Plant Contingency shall not include a Maintenance OutageIDerate. Uncontrollable Force" shall have the same meaning as defined in the WSPP Agreement; provided, pursuant to Section 10.1 of the WSPP Agreement. the parties hereby agree that the firm contractual mmsmissioD path being utilized by PacifiCorp to transmit Paul deliveries hereunder shall be the FPT ContraCt. Notwithstanding the foregoing, termination or assignment of the FPT Contract for any reason shall not be considered Uncontrollable Force. Section 2 - Term & Termination Subject to the receipt of the approvals provided for in Section 3, this Confinnation Agreement shall become effective ("Effective Date ) upon its execution by both Parties. Unless rnutual1y agreed otherwise, deliveries contemp1atcd hereunder shall begin on June I, 200 1. This Confmnation Agreement shall terminate at HE 2400 on June 30, 2007 . AppHcable provisions of Uris Confirmation Agreement shall continue in effect,after termination to the extent necessary to satisfy the terms and conditions of this Confirmation Agreement and, as applicable, to pTovide for final bi11ings and adjustments related to the period prior to termination and payment of any money due and owing either party pursuant to this Confirmation Agreement. Section 3 - Regulatory Aporovals If required by FERC, TEMUS shall me this Confirmation Agreement with FERC within 10-days of its execution by both Parties or when otherwise required by the FERC to be rued, whichever is later. Jf the FERC does not issue an order accepting this Conf1fIT1ation Agreement for filing in its entirety and without change, the parties shalt exercise best efforts to amend the Confinnation Agreement to comply with the FERC order or negotiate a repl~mcnt agreement providing similar benefits to both Parties within 60-days following FERC's issuance of such order. In the event the Parties are not able to negotiate a replacement agreement, the ParUC5 agicc to submit to the arbiuation procedures contained in the WSPP Agreement in order to detCnnine the terms and conditions of a replacement agreement that complies with the FERC ordcr. \ ". ', ~ ' ". - ~ Section 4 - Deliverv Rate and Contrad Ouantinr For the time period June 1,2001 through June 30, 2002, PacifiCorp shall purchase and TEMUS shall sell, 300 MW, as scheduled pursuant to Section 10. each month at a minimum monthly load factor of 94%, based on all hours of the month, and ma):imum monthly load factor of 100%, based on all hOUTS of the month. TEMUS shall be obligated to deliver the minimum monthly load factor notwithstanding Forced Outagc, Curtailment. Maintenance OutageJDerate, or Economic: Displacement during such month. For the time period July 1, 2002 through June 30, 2007, PacifiCorp shan purchase and TEMUS shall sell. 400 MW, as scheduled pursuant to Section 10, each month at a minimum monthly load factor of 94%, based on all hours of the month, and a MAY-04-2000 13:23 SALTA', 267 6906 03/23 Centralia" means the Centralia generation plant located near Centralia, Washington that has a nameplate generation capability of 340 MW produced by twO separate generation units. Curtaihnent" means a reduction in Centralia generation capabnity due to an unplanned forced de-rating, on either, or both, Centralia unites), as categorized by standardized NERC event typeS Dl (immediate). D2 (delayed), or D3 (postponed). Economic Displaceme~t" or "Economically Displace" mcan5 any hour that the generation capability of Centralia is reduced due to economics or due to NERC' definition of a NC (non-curtai1ing) event The rcd.uction of generation capabi1ity in .order for TEMUS to bid ancillary services to an independent system operator, such as the California Independent System Operator. shall not consUnne , Economic Displacement. Effective Date" meaJ1S the date that both Parties execute this Confinnation Agreement and the receipt of FERC acceptance pursuant to Section 3. Floor" means the minimum S/MWh quarterly price for energy as applied pursuant to the methodology in Section 7.2 and as listed in Table B. ContraCt" means PacifiCorp s BPA contraCt #14-03-09228. The FPT Contract provides fnm transmission service for PacifiCoIp from Paul to various points of receipt on PacifiCorp s system. across the BPA tranSmission network. Forced Outage" mcans a reduction in Centralia generation capability due to an unplanned forced outage on either Ccntralia unit as categorized by standardized NERC event typeS 01 (immediate). U2 (ddaycd), U3 (postponed), or SF (startUp faUure). HE" means hour ending. Maintenance OutageJDeratc:" means a reduction in Centralia generation capability due to a planned maintenance de-rating OJ' outage as categorized by standardized NERC event types MO (maintenance outage). :ME (maintenance outage extension), PO (planned outage). PE (planned outage extension). D4 (maintenance ~rating). or PD (planned derating). Netting Agrc:cment" means the Mutual Netting/Settlements Agreement between the Parties. dated January 1, 1999. as amended. NERC" means the North American Electric:: Reliability Council. ~ . ,...J f"'. Exhibi t B Schedulina Procedures Annual Forecasts: By December 10 of each calendar year, PacifiCorp shall furnishRedding with a nonbinding estimate showing PacifiCorpl anticipated monthly usage of San Juan energy for the followingcalendar year. Monthl v Preschedules \ By the 24th of each month, PacifiCorp shall furnish Reddingwith a nonbinding estimate for the following month of thehourly usage of San Juan 'energy. Such estimate may be in theform of a typical weekday, Saturday, and Sunday/holiday hour-by-hour schedule. Dail v Preschedules: Prior to 07: 50 hours each work day, PacifiCorp shall furnisha preschedule for the following day (s) showing the intendedusage of San Juan energy. Real-Time Schedules: Redding shall make best efforts to notify PacifiCorp of anychange necessary in prescheduled quantities necessitated by anoperating emergency or outage and the expected duration of theoperating emergency or outage. PacifiCorp shall make best efforts to notify Redding of anychanges necessary in prescheduled quantities due emergencies on its system. Real-time schedule changes shouldbe reported to Redding at least 4S minutes prior to theaffected hourly scheduling period and, preferably, 60 minutesprior to the affected hourly scheduling period. '") :':;==:~ ::= - ~ee-- "'" ""'--...-"~; -= _.: ' C:_= I """. -: ---- - .. ::--~- - .. ..--- -- .. -.. - -.; - ,..; - ".. ... .....---- . ,: - ...-- .,,."'- -- ... serve -- ...-- ...... ... ... --""'" ..... - -.. '---.... -.,.. -- pu..-;:ses an equal. u:: := :':::zcn'::a c~pa.ci::t =:.;:=: :.: U:-.i: ::0. and. t::i: ::0. : . :::. is recC;-..i.:ed. t~t ::-..:.z Service S checiula :: is entered. i::1::: =0: '":e pw:-;ese of =eciuc:.::.q t..~e reserve requi=emenu of M-S-itand ':'::cscn only and. i: is understood. tt3.t :10 ownershi; =:.;:.ts are in any way to be af:ecud. by t:is Service Schedule i:. E:.!t is unaerstcod ~~~ t ~-S-R will count as c3paci:y one-rialf of i:: qenera.c.:::. enc.:.lement i::. U:Ut :10. .. and. ona quar:~r :.:. ead1 0 f U.u. 'to ::0. ~ and. U:Ut ::0. 2. ana. will s c:neciulaf= t.:ese wU.'t:: based. on th.u.r avai..la.bi.~i:7.For purpose. af ene.r;-J ac:c::ut:.::.q, M-S-R hourly enerq-J ~entitleman= shall. ba ciatar- mine~ by Imutiplyin; t.ha H-S-a participation percan1:a.qa expnuaci as a daC"~l quantity by Un1: No.4 hourly capAbi Uty less t.h& .H-S-a hou:ly c::u:t~; ""1111 of Unit. Hc. anci Unit. Ho. 2 la.. t:!za H-S-R hoa:ly c~; ""8 1: of Unit. No.Energy s checiules will b. adjusted. ta reciuca imba.~a.ncas in tea cour:a of ~e yea: :.uaci. an the M-S-R en1:it.lem8Z11::.Ad.jwn:msn= in the cieJ.j,veriasof ene~ to M-S-a durin; the fi::: t-oilO months of the succeecU.nq calendar year will lJe made based upon the year end. equali:at:Lcm. Th1.s two-~nth period may be extended lJy mu1:1:al a.qne- men1: of t:e Operati:ns CO:m:i~:ee i: .,iin1:er or spri:q ::.ainte.nance is sdledulaci on rJni: ~lo. 1.. Unit :10. : or uni.t :10. .. and ::e:esul~q ener~J shi=: is i~ a ba.lanci:q di=ec~i:n. 1:.~:o t .. - 1':':':': ,iill =e p laced. en t..":e shari:; 0 = =i;serves i:1 C=.i: :Zo. :.. Cni: ::0. :: or Uni t ::0. ... However. ener~. i=bal- ances =;sui~; ===: t..":e s~a.ri:q 0: =aser...es will =e l':":':':iao. ,=-~e enerr;-.t eq\U.-alen: 0: 60 days' c;:era.~~=: at ~~Q perce:n: capa- 16.To any person or entity wholly owning, wholly owned by, wholly owned common with the Party making the assignment. No assignment, merger,or consolidation shall relieve any Party of any obligation under this Agreement.Subj ect to the foregoing restrictions in this Section 16, this Agreement shall be binding upon,inure to the benefit of,and. be enforceable by the Parties. ~~d their respective successors and assigns. IX WITNESS WHEREOF, the Parties to this Agreement have caused this Agreement to be executed in their respective names by their \.- respective officers thereunder duly authorized. By: Ti=l"-, 4...h.k "roved " ,---/'- .-t.-.;1'PA' ~~ -(~~... W. LEONARD WJJQGATE City Attorney Address: 750 P3rkview Avenue Attest: Reddin~ CA 9600 I PACIFICORP By: j1u:,.a.o- P. Title:Vice President Address: 825 NE Multnomah. Suite 625 Portland. OR 97232 13. 14. obligations not expressly provided herein, the Parties shall attempt in good faith to renegotiate the terms and conditions of this Agreement so as to preserve the original intent contemplated by the Parties.In the event the Parties are unable to renegotiate the andterms conditions this Agreement, this Agreement shall terminate within 60 days of receiving notification from FERC, any agency, or any court of competent jurisdiction requiring material modifications to this Agreement. Waiver:Any waiver by a Party to this Agreement of its rights with respect to a default hereunder or with respect to any other matter arising in connection herewith shall not be deemed to be a waiver with respect to any subsequent default or matter.No delay,short of the statutory period of limitations, in asserting or enforcing any right hereunder shall be deemed a waiver of such right. Ind~ific:at:ion:Except as provided in this Section, each Party hereto hereby assumes all liability for injury or damage to persons or property arising from the act or neglect of its own employees, agents, or contractors and shall indemnify and hold the other Party harmless from any liability arising therefrom.Notwithstanding the foregoing, no Party shall be liable,whether contract ,.,arranty,stricttort, liability, to the other Party for any injury or death to any person or for any loss or damage to any property caused by orarising out an electric disturbance that Party' 5 10.Notices:~ll Nritten notices, demands, or reques~s required by the Agreement or the provisions hereunder,including billing invoices, shall be considered given when delivered in person or prepaid telegram or sent by first-class mail,postage prepaid,deposited in the u.s. mail,directed as follows: To Redding: Electric Utility Director City of Redding ' 760 Parkview Avenue Redding, California 96001-3396 ' To PacifiCorp: Vice President, Power Systems and Development PacifiCorp 825 NE MultnOmah, Suite 485 Portland, Oregon 97232-4116 ' with CQ'OV to: Manager, Contract Customer Administration PacifiCorp 825 ME Multnomah, Suite 625 Portland, Oregon 97232 -4116 The Parties may change at any time the persons to whom noticesare addressed,or their addresses,by providing notices thereof as specified in this Section 10. 11.Uncontrollable Forces:Neither Party to this Agreement shall ::::msidered :..n default perf ormance any this Section 7 are exemplified ' Exhibit C to this ,..... Agreement. Bond ':'ovenan riction Cs)PacifiCorp hereby acknowledges that federal tax law imposes certain restrictions regarding the terms and conditions under which Redding is permitted to deliver San Juan energy to PacifiCorp without adversely affecting the tax-exempt status of the bonds issued by MSR to finance its share of the facilities comprising the San Juan generating station.PacifiCorp hereby represents and covenants that to the extent any energy exchanged by Redding under this Agreement is exchanged on a nonsimultaneous basis, PacifiCorp shall use such energy for the purpose of satisfying f"""one or more of PacifiCorp' s peak demands.Redding and. PacifiCorp agree that one manner in which the latter may satisfy the foregoing covenant is by using San Juan energy in place of hydroelectric energy to meet its then-current load and thereby continue storing water "behind the dam"forpurposes of meeting subsequent peak load ( s) .In no event shall PacifiCorp be liable to any party in connection with any impairment or loss of the tax-exempt status of bonds issued by MSR in connection with San Juan, and Redding shall indemnify and hold PacifiCorp harmless in regard to any claim associated with any such impairment or loss. Scheduling' :~ll scheduling under this Agreement shall be in accordance with the terms of Exhibit B to this Agreement. Such terms are premised in part upon Redding' s scheduling to take delivery of the lesser of (1) Redding' Maximum Entitlement,( 2 ) 130 GWh of San Juan Unit 4 ener~~ provided that this obligation shall be reduced by an amount equal to the reduction in Redding's Maximum Entitlement caused by partial or complete forced outages.This obligation shall not be reduced by any energy to which PacifiCorp takes delivery under the Exhibit A to this Agreement. In the event of a termination of this Agreement. between January 1 of the calendar year that such termination becomes effective and. the termination date, inclusive, PacifiCorp shall have the right to take delivery of up to Redding' Maximum Entitlement.During that same time period, PacifiCorp shall have the obligation take delivery of the lesser of (1) Entitlement. Redding's Maximum (2 )10.8 GWh multiplied by the number of months applicable to such time period, provided that this obligation shall be reduced by an amount equal the reduction in Redding' Maximum Entitlement caused by partial or complete forced outages. In addition to the rights and obligations set forth in Section 7 4 of this Agreement,PacifiCorp shall have the right to take delivery of Power and the obligation to make available Power "..lnder :he reserve- Redding in consideration of receipt of San Juan energy shall be delivered at COB or as otherwise mutually agreed by the C_- Parties.The delivery of such Power to Redding shall be consistent with Section 7 of this Agreement and with all Power delivery provisions under the Existing Agreement. Power Exchanae Obliaation~ Reddinq Deliveries to PacifiCorc:Redding's obligation to deliver Power to PacifiCorp shall be as follows: Maximum CaDacitv Deliverv:Redding shall make available to PacifiCorp its maximum share of capacity from San Juan through a combination of Redding' s rights -...J to Unit 4 Power and Redding's rights under Exhibit A to this Agreement, provided that, if Redding' s rights to SanJuan Power are reduced during San Juan unit outages,PacifiCorp's rights to Power under this Agreement shall be reduced to the amount available to Redding under Exhibit A to this Agreement. Reddinq's Riqhts to CaDacitv:To the extent, in any given hour, PacifiCorp does not exercise its full rights under Section 7 .1 of this Agreement, Redding shall have the right to schedule for its own accountcapacity (and associated energy) equal to the difference between the maximum amount of Power made available to Redding in a given hour and the amount of Power that is TEP" :neans Tucson Electric Power Company or itssuccessor. TEP Interconnection Agreement" means the Intercon- nection Agreement between TEP and MSR, dated September 20, 1982, as amended, or its successor agreement. Te~ and Termination Effecti7e Date and Termination:This Agreement shall become effective upon execution by both Parties.Service under this Agreement shall commence at the hour ending 0100 Pacific Time on May 1995 and,except as provided in Sections and 5.this Agreement,shall be coterminous with the Existing Agreement. Reaulatorv Annro al :PacifiCorp shall file this Agreement with the FERC in a timely manner subsequent to its execution.PacifiCorp shall provide Redding with a copy of the filing prior to submittal to the FERC, and Redding shall file letter of concurrence with the FERC supporting PacifiCorp' s filing of this Agreement.I f the FERC does not approve or accept this Agreement for filing in its entirety, the Parties shall exercise best efforts amend this Ag=eement ::0 comply with the FERC action manner consistent ~ith the Parties' original intent.In the event such an amendment is not executed by the Parties within 60 days (:Jr l:::mger i.f the Parties mutually agree)of the Power from the San Juan proj ect and under the TEP L.. Interconnection Agreement. Redding and PacifiCorp are Parties Existing Agreement under which Redding purchases system capacity and associated energy from PacifiCorp .Such purchases are delivered to Redding at COB. The Parties desire to enter into this Agreement under which San Juan energy will deli vered by Redding' PacifiCorp in exchange for energy of approximately equal value delivered by PacifiCorp to Redding. Acrreemen t: :In consideration of the foregoing, the Parties \.-t hereby agree as follows: Defini t:ions:As used in this Agreement, the following' terms have the following meanings when used with initial capitalization, whether singular or plural: II Agreement" means this Power Exchange Agreement between Redding and PacifiCorp, including Exhibits A, B, and C, which are attached this Agreement and made part this Agreement. Annual Variable Costll means that certain ,."eighted average variable cost derived in accordance with Exhibit 8 to -:he ::xisting ;greemem:and used :.n Exhibi t r'"this -'I ' POWER EXCHANGE AGREEMENT BETWEEN PACIFICORP AND THE CITY OF REDDING Preamble:THIS POWER EXCHANGE AGREEMENT ("Agreement"), dated this ~ay of April 1995, is between PacifiCorp, an Oregon COrporation, and the City of Redding, a municipal corporation organized under the laws the state California ("Redding" ) . PacifiCorp and Redding are sometimes referenced hereinafter collecti-tely as Parties"and individually Party. 2 .ExDlanatorv Recitals MSR has a 28.8 percent (143 MW) ownership interest inUnittheSanJuancoal-fired power proj ect northwestern New Mexico. 2 - 2 ""'/ Service Schedule E (dated January 23, 1985, appended asExhibit A to this Agreement)the TEP Interconnection Agreement, sets forth terms and conditions under which TEP and MSR share the reserve capacity and the reserve liability associated with and occasioned by their respective ownership interests in San Juan Units 1 , 2, and Among other things the TEP InterconnectiQn Agreement provides MSR with reserve- \...0sharing rights and obligations. ..., ":I .:.. - Redding has a 15 ~ercent entitlement in MSR's rights to Agreement. California-Oregon Border"(COB)means the boundary between the states of California and Oregon. EXisting Agreement" means the Long-Tenn Power Sales Agreement between PacifiCorp and Redding, dated October 19,1993. FERC" means the Federal Energy Regulatory Commission. GWh" means gigawatt-hour, a unit of electrical energy. "Maximum Entitlement"Redding'means percententitlement (15 percent of MSR's 28.8 percent entitlement) to San Juan Unit 4 energy production. MSR"means the M-S-R Public Power Agency,Joint Exercise of Powers Agency duly organized under the laws of the state of California and consisting of the Modesto Irrigation District , the City of Santa Clara, and the City of Redding. MW" means megawatt, a unit of electrical capacity. MWh" means megawatt-hour, a unit of electrical energy. Power" means electrical capacity and associated energy. FERC's action, either Party shall have the option to tenninate this Agreement upon thirty days tlritten notice to the otherParty.In such event ,any liabilities accrued between the effective date of ,this ,Agreement' .and the effective date of , ,, "::'.. termination, inclusive, shall remain i~tact. Early Termination By Reddina'Redding shall have theright to terminate this Agreement . upon four months priorwrittennotice,provic;ied that event shall any termination under this Agreement be effective prior to the hour ending 2400 Pacific Time on September 30" 1995. 5 .Early Termination BY PacifiCorc:PacifiCorp shall have the right to terminate this Agreement upon one year' s priorwritten notice. Point (8) of Delivery Deliveries to PacifiCorc:Power delivered by Redding or its agent (s) pursuant to this Agreement shall be delivered to PacifiCorp at the Palo Verde, Westwing, Moenkopi, or San Juan delivery points '(as ' d~signat:ed at any time (subject to the provisions of Section 8 of this Agreement) by PacifiCorp), or as otherwise mutually agreed by the Parties. The delivery of such Power to PacifiCorp shall be in accordance 'tlith Section of this Agreement. Q. ~Deliveries to Redding:Power deli yered by PacifiCorp to being scheduled by PacifiCorp for that hour. Minimum Deliv'eries:During each hour in which San Juan Unit 4 is operating,PacifiCorp shall have the obligation to take delivery of a minimum of 9 MWh/hr. During times when Unit 4 is unavailable, this obligation shall become zero. Enerqv Deliveries:The following energy delivery provisions shall apply: 7 . 1 . 4 . 1 Beginning with the commencement of service pursuant to Section S. 1 this Agreement and ending December 31 1995,inclusive,PacifiCorp shall have the right to take delivery of up Redding's Maximum Entitlement.During that same time period, PacifiCorp shall have the obligation to take delivery of the lesser of (1) Redding' Maximum Entitlement, or ( 2 ) 86 . 7 GWh of San Juan Unit 4 energy, provided that this obligation shall be reduced by an amount equal to the reduction in Redding's Maximum Entitlement caused by partial or complete forced outages. 1.4.Each calendar year thereafter, PacifiCorp shall have the right to take deli".rery of up to Redding's Maximum Entitlement.During those same :~me periods, PacifiCorp shall have the obligation sharing terms of Exhibit A to this Agreement. Paci:iCoro Deli ~eries to Redding:Energy delivered by Redding to PacifiCorp from San Juan shall be exchanged for energy to be delivered by PacifiCorp to Redding under the Existing Agreement accordance with the following methodology : PacifiCorp shall deliver an amount of energy to Redding equal to the amount of San Juan energy delivered to PacifiCorp multiplied by 1.372 provided that, during any calendar year,for any San Juan Unit energy delivered to PacifiCorp in excess of the minimum amount derived pursuant to Section 7. 1.4 of this Agreement, the aforementioned 1.372 shall be reduced to 1.100 (or lower as mutually agreed from time to time by the Part1es) . Redding's obligation to take delivery of energy under the Existing Agreement shall be reduced by the greater of the amount derived in Section 7.1 of this Agreement or the amount derived in Section 7. 4 of this Agreement multiplied by 1.372. 7 .PacifiCorp' s obligation to deliver energy Redding under the Existing Agreement shall be reduced by the amount deri 7ed in Section 7.1 of this Agreement. The accounting associated with the foregoing provisions of andl or notification obligations to other parties.On an ongoing basis during the term of this Agreement, Redding shall use best efforts facilitate !?acifiCorp'real- time scheduling and system operation requirements (e. g., timing anddirect communications with other entities associated with Redding'San Juan resource)they pertain this Agreement.TO the extent the aforementioned obligations are mitigated for Redding,Redding shall use best efforts provide commensurate relief for PacifiCorp. Audit: Riaht:s:The Parties, at their own expense, shall have the right financial to audit and to examine any operating and I or data related any item set forth this Agreement.Any such audit shall be undertaken by the auditing Party or its representatives at reasonable times and in conformance with generally accepted auditing standards.The right to audit any information shall extend for a period of five years following the transaction to which such information pertains under this Agreement.Both Parties fully agree to cooperate with such audit and to retain all necessary records or documentation for the entire length of the audit period. Both Parties shall take all steps reasonably available to secure the confidentiality of each other's accounting records and supporting documents.If any such audit discloses that any discrepancies as to the intent of this Agreement, both Parties hereby agree to attempt to remedy such discrepancy in an expeditious manner. 12. obligation hereunder ~= failure of performance shall be due toan Uncontrollable Force.The term "Uncontrollable Forcen means any cause beyond the control of the Party affected, including, but not limited to, failure of facilities, flood, tsunami, earthquake, storm, fire, lightning, epidemic, war,riot,civil disturbance,labor disturbance,sabotage,andrestraint by court order or public authori ty ,which, exercise of due foresight,such Party could not reasonably have been expected to avoid;and to the extent that by exercise of due diligence,it shall not have been able to overcome.Party shall however,not,relieved ofliability for failure of performance the extent such failure is due to causes arising out of its own negligence or to the extent such failure is' the result of removable or remediable causes which it fails to remove or remedy with reasonable dispatch.Any Party rendered unable to fulfill any obligation by reason of an Uncontrollable Force shall exercise due diligence to remove such inability with all reasonable dispatch and shall notify the other Party such Uncontrollable Force soon practicable.Nothing contained herein, however,shall be construed to require a party to prevent or settle a strike against its will. Requlatorv Modification:In the event that subsequent to the approval referenced in Section 5.2 of this Agreement, the FERC or any agency or court of competent jurisdiction materially modifies any term or condition of this Agreement in such a ~anner that either Party is required to incur new or different '".,\.,.,., 0"' 15. 16. elect:ric syst:em,'tlhether or not such electric disturbance resulted f=om that party's negligent, grossly negligent, or wrongful act: or omission, excepting only action knowingly or intentionally taken, or failed to be taken, with the intent that injury or damage should result therefrom or which action is wantonly reckless.Each Party releases the other Party from,and shall indemnify the other Party for,any such liabili ty As used in this Section,(1)the term "Party" means,in addition to 'such its directors,Party itself, officers,and employees;(2 )the term " damage" means all damage,including consequential damage;and (3 )the term person" means any person, including those not connected with either Party to this Agreement. Dis~ute Resolution:The Parties shall make best efforts to settle all disputes arising under this Agreement as a matter normal business and without litigation.recourse Pending resolution of a disputed matter, the Parties shall continue performance of their respective obligations pursuant to this Agreement. Assianabilitv:This Agreement shall not be assigned without the prior written consent: of the Parties, which consent shall not be unreasonably wit:hheld, except: 16.To any person or entity into which or with which the part:y making the assignment is merged or consolidated or to which the part:y transfers subst:ant:ially all of its asset:s. --, - -- t:XItIBIT .\ :~I'l'~Z=:::::Zc:-..:::: n.G ~~~~.~ between TUCSC:; ~==:':t: ~OWER CC:~ANY and. M-S-R PUBUC: POWER A SE:~lIcr. S~DCI.Z RESE~ SHARnIG Thios Service SQeciule E is agreeci upon as par-- of t:a In'ter-ccnnec~=n Aqreeme.n-: enu=reci ~tc t1etween 'l'UCSON J:".UC::::UC ~OWE1t coz.mANY ("Tucson'" and. M-S-R PUBUC POWER AGENC% ,"M-S-R" 'l'h:L.s Service Schedule E shail be deemeci effecc.v8 wAc the purd:asa of an unr1i viaecl 28. a, ownership interest in SaD. Juan G8I1en.ti:q Sb,c.cn Un1: No.4 (W Unit No.f=m iNK is c::omplabaci by M-S-R. the life of t1n;L: NO.4 0: wit:i1 t~taci by either 1'U1:-/ Upcmth:ee (3) y~s ad.vance wri::en ncc.ca. 'l'his Service Sd1eclula shaU ba in effeCt t.t1e:eaft:aJ: fa: 'l'his Service Schedule E sets forth. the tums ami ~d1 ticns "!1"~r which the P~as shall shaJ:e the resene capaci:y and. the rese:ve liab; ty associated. with ancl occasioned by 1"h.ir respecc"'Ie ownushi;= interest in Unit No.4 and in San. JuanGenera~q Stat1cn Unit ~:Q. 1 and Unit ~lo. 2 "'Unit ~IQ. 1" and. Un1: :10. 2" -.... :; is c=n:am~la~eci ~~at ~-S-R will acqui=e an undivided 22.21 o'Nners::.:.; i~te=e.st: i.= Unit ~:Q. 4 on May 1, 1995.Said 28. S \ owners::.i; interest i~ Unit ::0. 4 is eSt~teci to be lJS M1i of -"""~ -.. .....,.; ene 'P""". '--=- --.l ......... -~~ . hen ~-S-? a.CI:~=::;s saie. o'..mersn.:.;: i;-.:erest :;-. Uni~ No. ~, t~e Ea=~~as here~y agree ~~~t ~-s-a will ass~qn to~c::.. ~~::~~:~. . ,~. .~~~=~- ~? e:e=~. ~=~~;~~=:~ ::= ~~a M-S-~ s~Q=a 0: Uni. ~ ~:o. wi.l~ =e i::--:':"~~eci :: l'NM by M-S-? anti s~-~=' enerqy o.bl~;.J.c.=::.s ==: ~=.a T~=:=::. snUB 0::: U:i: ~:o. :. anci U:-.i: ~lo. : wiUbe f~:~ci tQ PNM by T-.:cson. When Unit ::0. .. is cicwn. ':'-.:c:on will scheciule s1:a=-up ener~.l to PNK fer :-1-5-R. :~ Uni.:. ::0. 1 or Unit ::0. 2 is ope:adonC;. M-S-? will schedule a li.'te amount of ener~1 f:cm its capacit7 riqhtz in said opera '!!~..: q Unit to T~on.If both Unit :10. 1 and. Unit ~o. 2 are not .cpuati::.q, Tucson wiU :naintai:1 an acccunt of ener~.l s c:hed.uled to PNM fo: ~-S-R and M-5-R will rB1:u..",,: a like - "" amaun1: 0: enerqy to Tt:cson wi~ 60 days of :.:.e date tl1a.t Unit. Na. 1. Unit No.2 or Un1.t No.'; is-. retw::eci to service. IA the eVent San Juan Un:Lt.~ld. 1 or Unit NO.sbcuJ.cl. be subj ected ta an enl!l~ded. Qu1:a.qa 'ather than a. na:ma.l main't.."... aU1:a.qa, Tucscm will usiqn an equal. amaunt of Besana Sharinq capacity ta H-S-a f=cm the a'the: San Jum Ua.1t until the San J&aII. Un1t expari"ucinq the eXtencied ou1:a.qa is retu:neci. to service. IA. the event San Juan Un:Lt No... is suejeC1:eci to an. extended ou1:a.qa ether a. norma..l. ma.in~I!I"""I:1~e eutaqe, M-S-R and Tucson will. four months af~ t!1e start: of the outaqe, sua- pend Reserve Shari:q until San Juan Unit No.4 is retur:eci toservice. Executed. t.~s '13~day of j~.wd ,,- 1981 ? . TUCSC:~ E:.zc-.~.!C POWER C:MPANY ~1-S-:t FUEI.:: :im'lE:! ~~z:,=:: ~6/. /. --- Exhibit B Schedulinq Procedures Annual Forecasts: By December 10 of each calendar year, PacifiCorp shall furnishRedding with a nonbinding estimate showing PacifiCorp'anticipated monthly usage of San Juan energy for the followingcalendar year. Monthly Preschedules: By the 24th of each month, PacifiCorp shall furnish Reddingwith a nonbinding estimate for the following month of thehourly usage of San Juan 'energy. Such estimate may be in theform of a typical weekday, Saturday, and Sunday/holiday hour-by-hour schedule. Daily Preschedules: Prior to 07: 50 hours each work day, PacifiCorp shall furnisha preschedule for the following day (s) showing the intendedusage of San Juan energy. Real-Time Schedules: :2 . Redding shall make best efforts to notify PacifiCorp of any change necessary in prescheduled quantities necessitated by anoperating emergency or outage and the expected duration of theoperating emergency or outage. PacifiCorp shall make best efforts to notify Redding of anychanges necessary in prescheduled quantities due emergencies on its system. Real-time schedule changes shouldbe reported to Redding at least 45 minutes prior to theaffected hourly scheduling period and, preferably, 60 minutes prior to the affected hourly scheduling period. :':.:.:==::. ...:_- -"""'" .....---- -"~ i -= -~ ' C::- ::' .i!."'. - : -- --:.--- --- -... ::"'-~-"'~ .. u_-- -- -. - -- ... i::. ~:.i: ::0. ~ anc. ::.:.:==::. ....ill ~::. t:~-: .J.ss:.:;:: :: ~-S-? === =aserve ~u..-;=ses an equal ~u::: == ':':':'==0:1. = c~pac:.::t =:.;h-:: ;,::. U;-.i: ::0. anti t:::.i: ~:Q. : . !:. is recc;n:.:eci t~t :.~~ Se.rvice Scheciule E: is en:ereci ut:: :0: :.:e pur:,cse of =eciuc:.:.q t.~e reserve requi=amen:s of M-S-a. and :'~cscn only and. i: i:3 understood. t.-:10 ownershi; =:.;~ts are in any way to be affected. by t:is Service Sched.ule E. It: :.s uncierstcoci t.":~t M-S-R will count as capac:.~7 one-half of i:z qenerati.:n enc.:lement :.::. UnJ.; :10. .. and oneqUU:~r i:. ea-en 0: U.u. ::0. : and. Unj. t ::0. 2. ana. will oS c::1eciulaf:c: t.:ese wU. t:i based. on thur avai.lam.li:7.For purposes o~eD~; ac:c=uc:q, M-S-R hourly enarer; Joentitlemena shall ~. ciabr- m:i.:a~ by muluplyinq the H-S-a Partic.ipaticn percentaqa exp:auaci as a da~-t"'sl quantity by Un1.t No.4 hourly capAbility less tba l-l-S-a haa:ly curt:!t-t 1"'.11 of Unit No.1 ami t1A1.t No.2 lass th& K-S-R hou:ly C~:!t-t 1"'~11: of Unit No.Energy schedules wUJ. b.adjusted. 1:c reduce imbala.zu:aa in the cour:a of ~a year :uaci en the M-S-il e.narqy entitlama::s.Adjus=ants in the cieJJ.verias of enerqy to M-S-R duri::.q tlle fi=:t t-olla mantns ef the succeadiAq c:al.enciar yeu will be macia based. upon the year end equa..li:a.d.cm. 'l'his two-month period. may be extended by mu~t:al aqree- me.n~ of t:e Opera~::ns Com:nittae i= -..;in~er or spri:; ::a.inte.nance is s dleciulaci en ani t ~lo. 1. ani t ~lo. : or UIU. t ~lo. 4 and. t:eresul~; ener~~ shi:t is i~ a balanci~; di=ec~i:::1. 1:.::0 t '; - l~: ....il:' ze p laceci on t..":e shari:; 0:: =aserves i;1 t:~i: ~Zo. :. Unit ~lo. :: or Unit ~lo. "*. 30we ver, ener~' i:bal- ances rasui~~; ==== :.":2 s~ari~; 0: =ase~res will =e l~:a~ ~~e ener~' equi~a1en~ 0: 60 dQYs' c~erat:i=::. at l~C percen~ c~pa- 16.TO any person or entity wholly owning, wholly owned by, wholly owned common ..,ith the Party making the assignment. No assignment, merger,or consolidation shall relieve any Party of any obligation under this Agreement. Subj ect to the' foregoing restrictions in this Section 16, this Agreementshall be binding upon,inure to the benefit of,and be enforceable by the Parties. ~~d their respective successors and assigns. WITNESS WHEREOF, the Parties to this Agreement have caused this Agreement to be executed in their respective names by their respective officers thereunder duly authorized. By: Ti=le, 4,. firm ftrPJ;roved --- tf- ,-"L.-,;JtP/l' e. ~.... -~~:Y'... W. LEONARD ~GA City Attorney Address: 750 Parkview Avenue Attest: Redding CA 9600 I PACIFICORP By : R. : ~- Ti tIe:Vice President Address: 825 NE Multnomah. Suite 625 Portland. OR 97232 13. 14. obligations not expressly provided herein, the Parties shall attempt in good faith to renegotiate the terms and conditions this Agreement so as to preserve the original intent contemplated by the Parties.In the event the Parties are unable renegotiate the andtems conditions this Agreement, this Agreement shall terminate within 60 days of receiving notification from FERC, any agency, or any court of competent jurisdiction requiring material modifications to this Agreement. Waiver:Any waiver by a Party to this Agreement of its rights with respect to a default hereunder or with respect to any other matter arising in connection herewith shall not be deemed to be a waiver with respect to any subsequent default or matter.No delay,short of the statutory period of limitations, in asserting or enforcing any right hereunder shall be deemed a waiver of such right. Ind~ification:Except as provided in this Section, each Party hereto hereby assumes all liability for injury or damage to persons or property arising from the act or neglect of its own employees, agents, or contractors and shall indemnify and hold the other Party hamless from any liability arising therefrom.Notwithstanding the foregoing, no Party shall be liable,whether contract warranty,stricttort, liability, to the other Party for any injury or death to any person or for any loss or damage to any property caused by or arising :)fout an electric disturbance that Party' 10. 11. Notices:~ll Nritten notices, demands, or reques~s required by the Agreement the provisions hereunder,includingbilling invoices, shall be considered given when delivered in person or prepaid telegram or sen~ by firs~-class mail, pos~age prepaid,deposited in the U. S.mail,direc~ed as follows: To Redding: Electric Utility Director City of Redding , - 760 Parkview Avenue Redding, California 96001-3396 To PacifiCorp: Vice Presiden~, Power Systems and Development PacifiCorp 825 NE Multnomah, Suite 485 Portland, Oregon 97232-4116 with CODV to: Manager, Contract Customer Administra~ion PacifiCorp 825 ME Multnomah, Suite 625 Portland, Oregon 97232-4116 The Par~ies may change a~ any time the persons to whom notices are addressed,no~icestheir addresses,by providing thereof as specified in this Section 10. Uncontrollable Forces:Neither Party to this Agreemen~ shall ::::msidered default.:.n perfo!:1nancel.n any --,--- -- this Section are exemplified ' Exhibit this Agreement. Bond ':ovenan Res riction (s)PacifiCorp hereby acknowledges that federal tax law imposes certain restrictions regarding the terms and conditions under which Redding is permitted to deliver San Juan energy to PacifiCorp without adversely affecting the tax-exempt status of the bonds issued by MSR to finance its share of the facilities comprising the San Juan generating station.PacifiCorp hereby represents and cpvenants that to the extent any energy exchanged by Redding under this Agreement is exchanged on a nonsimultaneous basis, PacifiCorp shall use such energy for the purpose of satisfying one or more of PacifiCorp'peak demands.Redding and PacifiCorp agree that one manner in which the latter may satisfy the foregoing covenant is by using San Juan energy in place of hydroelectric energy to meet its then-current loadand thereby continue storing water behind the dam"for purposes of meeting subsequent peak load (s) .In no event shall PacifiCorp be liable to any party in connection with any impairment or loss of the tax-exempt status of bonds issued by MSR in connection with San Juan, and Redding shall indemnify and hold PacifiCarp harmless in regard to any claim associated with any such impairment or loss. Schedulina:~ll scheduling under this Agreement shall be in accordance with the terms of Exhibit B to this Agreement. Such terms are premised in part upon Redding' s scheduling to take delivery of the lesser ( 1) Redding' Maximum Entitlement,(2) 130 GWh of San Juan Unit 4 ener~~ provided that this obligation shall be reduced by an amount equal to the reduction in Redding's Maximum Entitlement caused by partial or complete forced outages.This obligation shall not be reduced by any energy to which PacifiCorp takes delivery under the Exhibit A to this Agreement. 1.4.In the event of a termination of this Agreement, between January 1 of the calendar year that such termination becomes effective and the termination date, inclusive, PacifiCorp shall have the right to take delivery of up to Redding' Maximum Entitlement.During that same time period, PacifiCorp shall have the obligation take delivery of the lesser of (1 )Redding's Maximum Entitlement,(2 )10.8 GWh multiplied by the number of months applicable to such time period, provided that this obligation shall be reduced by an amount equal the reduction in Redding' Maximum Entitlement caused by partial or complete forced outages. In addition to the rights and obligations set forth in Section 7 4 of this Agreement,pacifiCorp shall have the right to take delivery of Power and the obligation to make available Power ~nder :he reserve- Redding in consideration of receipt of San Juan energy shall be delivered at COB or as otherwise mutually agreed by the Parties.The deli very of such Power to Redding shall be consistent with Section 7 of this Agreement and with all Power delivery provisions under the Existing Agreement. Power Exchanae Obliaations Reddinq Deliveries to PacifiCorc:Redding's obligation to deliver Power to pacifiCorp shall be as follows: Maxim~m CaDaci tv Deli verv:Redding shall make available to PacifiCorp its maximum share of capacity from San Juan through a combination of Redding' s rights to Unit 4 Power and Redding's rights under Exhibit A to this Agreement, provided that, if Redding' S rights to SanJuan Power are reduced during San Juan unit outages,PacifiCorp's rights to Power under this Agreement shall be reduced to the amount available to Redding under Exhibit A to this Agreement. Reddinq's Riqhts to CaDacitv:To the extent, in any given hour, Pacif iCorp does not exercise its full rights under Section 7 1 of this Agreement,Redding shall have the right to schedule for its own accountcapacity (and associated energy) equal to the difference between the maximum amount of Power made available to Redding in a given hour and the amount of Power that is TEP"~eans Tucson Electric Power Company or itssuccessor. TEP Interconnection Agreement" means the Intercon- nection Agreement between TEP and MSR, dated September 20, 1982, as amended, or its Successor agreement. Te~ and Te~ina tion Effecti7e Date and Termination:This Agreement shall become effective upon execution by both Parties.Service under this Agreement shall commence at the hour ending 0100 Pacific Time on May 1995 and,except as provided inSections5 .and this Agreement,shall coterminous with the Existing Agreement. Reaulatorv A,DDro al:PacifiCorp shall file this Agreement with the FERC in" a timely manner subsequent to its execution. file the filing prior to submittal to the FERC, and Redding shall PacifiCorp shall provide Redding with a copy of letter concurrence with the FERC supporting PacifiCorp' s filing of this Agreement.If the FERC does not approve or accept this Agreement for filing in its entirety,the Parties shall exercise best efforts amend this Ag::oeemen t ::0 comply /lith the FERC action manner consistent Nith the Parties' original intent.In the event such an amendment is not executed by the Parties within 50 days (ar 2.::mger ::.f the Parties mutually agree)of the Power from the San Juan proj ect and under the TEP Interconne.ction Agreement. Redding and PacifiCorp are Parties Existing Agreement under which Redding purchases system capacity and associated energy from PacifiCorp .Such purchases are delivered to Redding at COB. The Parties desire to enter into this Agreement under which an Juan energy will deli vered Redding PacifiCorp in exchange for energy of approximately equal value delivered by PacifiCorp to Redding. Acrreem.ent:In consideration of the foregoing, the Parties hereby agree as follows: Definitions:As used in this Agreement, the following terms have the following meanings when used with initial capitalization, whether singular or plural: Agreement" means this Power Exchange Agreement between Redding and PacifiCorp, including Exhibits A, B, and C, which are attached this Agreement and made part this Agreement. " . 1Ulnual Variable Cost"means that certain ",eighted average variable cost derived in accordance with Exhibit B to ,:he :::xisting gre emen t and used :.n Exhibi t ':0 this As SUrtn:'J t: i on~ Exhibit: ~ Monthly Billing Example UnderThis Aqr~~ent and the ~istinq A~~e~~ Delivery to pacifiCorp '" San Juan (Agreement" Existing Agreement' CapaCity COSt:~1sti~ ~e~~t ~Ual ~ri~le Costs,~ist~g A~~~t ~~~Ssion COSts: ~~~ ~ (1.372 . 14 000): 19. 208 ~sti~ ~~~t ~ (32 000 - 19 208) 794TOTAL 32,000 MWh 000 MWh ResUlt~ $16. 60 1JcH-f-t:)$16. 02/MWh $ 3. 09/MWh The billing tUlder the Existing Agreement wOUld appear as follows: Energy : ~acity : SO ~. $16.60~_~ ~SSi~: 32 000 8 $3.09/~'l'OT.u. BILL 12,792 MWh ~ $16. 02/MWh $830,000 $204,928 $ 98,880 Agreement. refers to this PO1rer Exchange Agreement between Re~~ PaCif1~~ 1!x1sting Agreement" refers to the Long-Te%1D POWer Sales A~~~t bet~~ Redd~g a~ Pacifi~~ dated Oct~er 19 1993. $1,133,80S :a......... PacifiCorp/P AC-02-1 February 5, 2002 IIP A Data Request No. 1. liP A Data Request No. 1.3: On page 4 lines 1-3 of Mr. Watters' testimony there is a reference to a short-tenDpurchase price in rates of $21.50 per MWH and $139 per MWH of actual cost.Please answer the foUowing: Please provide a listing of aU finD MWH, MW, dollars and$/MWH for each month that went into the development of the$21.50 per MWH figure; Please provide a listing of aU non-finD MWH, MW, doUars, and$/MWH for each month that went into the development of the$21.50 per MWH figure; Were the figures listed in "" and "b" above nonnalized? If the figures in "" and "b" above were nonnalized, please supplya listing of the actual finD and non-finD MWH, MW, doUars and$/MWH for each month. For each of the months of the deferral period , please provide theMWH, MW, doUars and $/MWH for any additional categories(stated separately) that went into the development of the $139 per MWH figure. Response to liP A Data Request No. 1.3: Witness: Stan K. Watters The $21.50 per MWh figure is the average prices of the short tenD finD purchases included in rates. Please refer to Widmer ExhibitNo., on lines labeled as "STF Purchases PPL" and "STFPurchases UPL" in both $ and MWh. Please refer to Widmer Exhibit No., on lines labeled "SecondaryPurchases" in both $ and MWh. Yes. The infonnation requested is provided as Attachment lIP A No. 3d. The $139 per MWh figure is the average actual prices of the same categories of transactions during the deferral period. Please referto Widmer Exhibits No.5 and No. At t a c h m e n t I I P A N o . 1 . 3d : 19 9 8 .1 a n Ma r Am : MA x .! . u n .l . 1 l i Au g ST F P u r c h a s e s 59 7 , 84 3 , 84 8 3 7 84 9 , 32 6 25 , 02 4 , 12 2 43 , 55 6 , 38 2 2 6 . 97 5 , 87 8 2 6 , 21 8 , 54 6 5 4 , 44 7 15 5 6 5 , 61 3 , 26 1 93 , 10 8 , 64 6 93 , 83 9 19 9 84 4 , 62 8 36 , 19 8 , 45 9 5 1 , 96 8 . 04 6 Se c o n d a l ) ' P u r c h a s e s 13 0 . 98 9 . 12 8 1 0 2 4 8 7 9 6 11 8 3 1 6 0 1 13 4 6 6 2 4 1 16 3 1 3 7 3 7 1 8 6 9 4 01 9 4 7 9 6 8 5 7 61 0 5 2 4 9 13 5 4 6 8 9 6 10 7 2 3 0 9 8 70 4 0 8 5 0 10 . 04 1 2 0 9 18 0 . 57 3 To t a l 72 8 , 63 2 , 77 4 4 8 , 09 8 , 12 2 36 , 86 6 , 72 3 57 , 02 2 , 62 3 4 3 , 28 9 , 61 5 4 4 , 91 2 , 56 5 5 9 , 24 4 , 01 2 7 1 , 71 8 , 51 0 1 0 6 , 65 6 , 54 2 10 4 , 66 2 , 29 7 49 , 88 6 , 4 7 8 48 , 23 9 , 66 8 6 0 , 14 8 , 61 9 MW b 19 9 8 .1 a n Ma r Am : MA x .! . u n .l . 1 l i Au g ST F P u r c h a s e s 24 , 81 7 , 88 4 95 0 01 2 1, 4 3 6 , 53 7 34 7 , 01 5 41 2 , 62 5 77 9 , 22 1 16 5 , 57 3 33 3 , 97 5 50 0 . 66 4 77 8 , 96 1 69 8 , 98 5 40 9 , 23 6 00 5 , 08 0 Se c o n d a l ) ' P u r c h a s e s 53 8 . 20 1 12 2 . Z B . 1 1 2 9 6 5 8 7 22 . M . 6 2 To t a l 31 , 35 4 , 08 5 2,4 2 9 , 52 4 15 9 , 31 8 02 7 , 70 7 33 1 , 17 0 07 5 , 80 8 3, 4 9 9 , 94 8 74 0 , 85 7 93 8 , 34 9 08 8 , 79 1 92 5 , 58 7 82 5 , 52 4 31 3 , 52 2 Sl M W b 19 9 8 .I a n Ma r Am : MA x .! . u n .l. 1 l i Au g ST F P u r c h a s e s 24 . 19 . 17 . 18 , 19 , 14 , 17 . 28 . 37 . 33 , 25 . 25 . 25 . Se c o n d a l ) ' P u r c h a s u 20 . 21 . 16 . 19 . 17 . 14 . 14 , 15 . 30 . 34 . 31 . 24 . 26 , To t a l 23 . 19 . 17 . 18 . 18 . 14 . 18 . 9 3 28 . 38 . 33 . 25 . 9 1 25 . 28 . PacifiCorplP AC-O2. February 5 , 2002 lIP A Data Request No. 1.4 lIP A Data Request No. 1.4: On page 4 lines 4-9 of Mr. Watters' testimony there is reference to the Company s strategy of relying on the market to fill in during the 'peaks' of a generally balanced load and resource situation..." Please answer the following:a. When was this policy of "relying on the market to fill in during the peaks" fIrst introduced? Please provide a copy of any internal or external statements thatreference such a policy of "relying on the market to fill in during the peaks . c. For each month from January 1998 through themost recent month available, what was the MWH and dollaramount of super-peak, on-peak, shoulder-peak, and off-peakpurchases (broken down between short-term-firm, intermediate-tenn-finn, long-term-firm, and non-firm). For each month from January 1998 through the most recent month available, what was the MWH and dollar amount of super-peakon-peak, shoulder-peak, and off-peak purchases (broken downbetween short-tenn-finn, intermediate-term-firm, long-term-firmand non-firm). For each month from January 1998 through the most recent month available, what was the MWH and dollar amount of super-peakon-peak, shoulder-peak, and off-peak sales for resale (broken downbetween short-term-finn, intermediate-term-firm, long-term-finnand non-firm). Please define the times of super-peak, on-peak, shoulder-peak, andoff-peak used by the Company in its response to "" and "above. With respect to the "generally balanced load and resourcesituation, for each month from January 1998 through the mostrecent month available, please list the energy and monthly peakdemand levels associated with the loads in the followinggrouPIngs: 11. Firm retail load Non-firm retail load Long-term-firm wholesale load Intermediate-term-finn Wholesale load Short-term-firm Wholesale load Non-fmn Wholesale load 111. IV. VI. PacifiCorplP AC-O:o.. February 5 2002 lIP A Data Request No. 1.4 V11.Other With respect to the "generally balanced load and resource situation , for each month from January 1998 through the most recent month available, please list the energy and monthly peak demand levels associated with the resources in the following groupIngs: IV. VI. Company-owned generation Long - tenn - finn purchases Intennediate-tenn- finn purchases Short-tenn-finn purchases Non-finn purchases Other 11. 111. Please supply the infonnation requested in "" through "" above in both hard copy as well as in an electronic version. Response to lIP A Data Request No. 1.4: a. RAMPP-4 introduced the concept ofthe bulk-power market as a resource for supplying resource requirements. b. Attached are copies of two examples where PacifiCorp has made reference to PacifiCorp s use of wholesale or bulk-power markets to balance its load and resource requirements with short-tenn or long-tenn products. Page 11 from RAMPP-4 is attached as Attachment 1.4.1. Attachment 1.4.2 is an excerpt from PacifiCorp filing with the Idaho Public Utility Commission for approval of the sale of Centralia plant and mine. Page 23 ofthe direct testimony of company witness C. Alex Miller indicates that PacifiCorp intends to balance its loads and resources with market purchases. The acknowledgement of this strategy is also noted in the Commission order approving the sale of Centralia. c. This response has not yet been completed. We will submit it as soon as possible. d. This response has not yet been completed. We will submit it as soon as possible. Super-Peak 13-20 (HE) On-Peak 22 (HE) Shoulder-Peak 12 and 21 22 (HE) Off-Peak 24 and 1-6 (HE) PacifiCorplP AC- February 5, 2002 IIPA Data Request No. 1.4 f. For monthly energy, please refer to Response to lIP A Data Request No. 1.14. All retail loads are now classified as finn. Both the long term firm and intennediate tenn finn wholesale sales are identified by contract. Short term firm and non-finn wholesale sales are grouped. There are no other loads. The information requested regarding monthly peaks is attached as Attachments lIP A 1.4(f)(i) and lIP A 1.4(f)(ii). i. The infonnation requested concerning monthly peak demands is provided in Attachments lIP A 1.4(f)(i) and lIP A 1.4(f)(ii). ii. The infonnation requested concerning monthly peak demands is provided in Attachments lIP A l.4(f)(i) and lIP A 1.4(f)(ii). iii-vii. The information requested concerning monthly peak demands is provided in Attachments lIP A 1.4(f)(iii-vii). g. For monthly energy, please refer to Response to IIPA Data Response Request No. 14. Company owned thermal generation resources are listed by plant. Hydro generation resources are grouped. Both the long tenn firm and intennediate tenn firm wholesale purchases are identified by contract. Short term finn and non-finn wholesale purchases are grouped. There are no other resources. The infonnation requested regarding monthly peaks is provided in Attachment lIP A 1.4(g). h. Responses to "" through "" are provided in both hard copy and electronic versions. Witness: Stan K. Watters IDAHO CASE NO. PAC-O2- P A CIFI CO lIP ADA TARE QUE ATTACHMENT IIPA 1.4(b. F.b-2T-O2 0.: I.PftI FrOil-PACIFICORP T-183 P.OO2/003 F-&38+503&&~TOI RAMPP-4 PbcliCorp Chapter 1: Introduction Pa~e 11 The new rules require PacmCorp to operate its transmission system more like a common carrier, much like the nahn"al gas pipelines. By limiting the way the utility can use its transmission system, it imposes a uwall" between the power side and the transmission side of the utility. The company will not be able to use its transmission system. to secure a competitive advantage. On the other hand, a more open national transmission system will give PacifiCorp greater access to the transmission systems of other utilities. It is uncertain what kind of return PadfiCorp will be able to get from existing and new transmission investments. FERC will probably continue to requize transmission-owning utilities to use embedded pricing (based on the cost of existing investments) rather than market- based pricing. The embedded pricing could be "postage stamp" prices(i., one charge regardless of the distance traveled) or "locationally sensitive prices" (i.e., c:hai-ges vary with the distance traveled or with differences in spot prices across the network). Any use of the company s transmission system lor its own transactions reduces the amount of potential revenue it can derive from other parties using its transmission ,system. Because of these trends, the company will carefully evaluate any transmission expenditures or investments. New FERC rules will have consequences for resource planning. Withall the changes occurring, PacifiCorp will have to re-examine its assumptions for transmission constraints and resource siting. RAMPP-5 will evaluate the impact of new PERC rules on the company s resource requirements. Wholesale Market as a Resource Because of changes occurring in transmission and in the power generation business, PadfiCorp expects to be able to increasingly rely on the wholesale market to meet its power needs, both from the non-firm market and from longer-term contracts. Power purchases give the company more flexibility in the way it can meet the energy needs of its customers. If the price of power on the wholesale market is very attractive and other conditions are right, the non-firm market could allow the company to delay other resowce acquisitions. Similarly, longer-term conttacts on the wholesale market can sometimes provide more cost-effective solutions to system needs than build~ng a new power plant. RAMPP-5 will contain more market-based resources than did RAMPP-4. IDAHO CASE NO. PAC-O2- P A CIFI CO lIP A DATA REQUEST ATTACHMENT IIPA 1.4(b. PPLII Miller/23 for the Mine. This will remove the Mine from PacifiCorp s books with no earnings impact. The book breakeven value was estimated at about $101 million at the time the agreements were signed, and is the value used in the Mine Sale Agreement. The current estimate of the mine breakeven is approximately $107 million, but this will be trued up and audited at the time of closing. The remaining proceeds will be split among the owners based on their Plant ownership percentages. PacifiCorp, for example, will receive approximately $215 million for its portion of the Plant ($554 M less $101 x .475). Total proceeds to PacifiCorp are about $316 million for the Mine and its share of the Plant. Gain on Sale Can you please tell us what the gain on the sale is? There is no gain on sale of the Mine. PacifiCorp s after-tax gain on the Plant is approximately $83 million. The calculation of the gain is shown in Exhibit Miller/l. 7. Replacement Power StrateK)' Please explain how PacifiCorp intends to replace the generation lost by the sale Centralia. The Plant was originally conceived as a seasonal-use generating station. However, the Plant has been dispatched as a base-load facility over most of its service life. Capacity factors have averaged 70% over the past five years, with a high of 84% in 1994 (largely a function of water conditions. Availability over the last five years has averaged 88%. The Plant is expected to produce about 4 million-megawatt hours annually for PacifiCorp. PacifiCorp will balance its loads and resources with market purchases. Direct Testimony ofC. Alex Miller IDAHO CASE NO. PAC-O2- ACIFICORP lIP A DATA REQUEST ATTACHMENT IIPA 1.4(f)(i ii) Pa c i f i C o r p s R e s p o n s e t o I I P A D a t a R e q u e s t N o . 1 . 4 . 1 - ' mo n t h l y p e a k d e m a n d l e v e l s ' - M e g a w a t t s 19 9 8 Ja n . Fe b . Ma r . Ap r . Ma y Ju n . Ju l . Au g . Se p . Oc t . No v , De c . Fi r m r e t a i l l o a d 58 2 17 4 20 6 65 1 34 8 22 9 05 9 81 4 65 7 67 9 03 8 32 7 No n - fi r n r e t a i l l o a d N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A Hi - v i wh o l e s a l e l o a d ( a ) 90 3 84 1 50 3 51 8 6, 4 0 7 75 1 5, 4 1 3 22 4 94 0 38 9 00 9 21 5 vi i Ot h e r ( b ) 12 7 12 7 39 6 32 6 32 7 34 8 39 4 27 5 19 9 9 Ja n , Fe b . Ma r . Ap r . Ma y Ju n . Ju l . Au g . Se p . Oc t . No v . De c , Fi r m r e t a i l l o a d 25 5 22 7 93 1 58 0 51 5 16 9 94 2 75 0 71 3 65 2 22 1 66 2 No n - fi r n r e t a i l l o a d N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A Hi - v i wh o l e s a l e l o a d ( a ) 48 9 79 8 62 5 39 8 66 9 99 5 64 1 30 6 64 6 68 5 57 1 4, 4 4 8 vi i Ot h e r ( b ) 12 9 18 2 21 3 65 1 32 7 46 8 63 3 13 3 13 7 16 0 20 0 0 Ja n . Fe b . Ma r , Ap r . Ma y Ju n . Ju l . Au g . Se p . Oc t . No v , De c . Fi r m r e t a i l l o a d 36 0 15 1 87 6 6, 4 2 0 80 7 92 7 8, 4 4 2 25 7 36 9 80 4 54 4 95 8 No n - fi r n r e t a i l l o a d N/ A N/ A N/ A N/A N/ A N/ A N/ A N/ A N/ A N/ A N/ A N/ A Hi - V I wh o l e s a l e l o a d ( a ) 80 1 23 9 84 8 81 5 47 4 71 5 05 6 21 4 17 6 86 3 29 3 24 2 vi i Ot h e r ( b ) 15 9 13 9 12 9 62 5 61 7 36 8 44 8 21 1 16 2 12 6 11 1 00 1 Ja n , Fe b . Ma r . Ap r . Ma y Ju n . Ju l . Au g . Se p . Oc t . No v , De c . Fi r m r e t a i l l o a d 68 2 59 1 12 1 94 9 28 3 56 7 84 5 89 3 29 6 76 2 39 7 62 5 No n - fi r n r e t a i l l o a d N/ A N/ A N/A N/ A N/ A N/ A N/ A N/A N/ A N/ A N/ A N/ A Hi - v i wh o l e s a l e l o a d ( a ) 34 0 59 0 34 1 83 9 68 2 24 9 98 7 20 0 94 4 98 9 78 2 31 9 vi i Ot h e r ( b ) 13 5 19 1 13 5 58 0 53 2 71 6 44 9 59 2 10 6 20 5 24 3 No t e ( a ) : i n c l u d e s r e q u i r e m e n t s a n d n o n - r e q u i r e m e n t s s a l e s f o r r e s a l e ; s o m e e s t i m a t e s m a y b e in c l u d e d f o r s m a l l r e q u i r e m e n t s c u s t o m e r s , No t e ( b ) : i n c l u d e s d e l i v e r y o b l i g a t i o n s a s s o c i a t e d w i t h s t o r a g e o r e x c h a n g e a c c o u n t s . ~ ~ (j ~ == s= ~ 0 z ~ ~ ~ ~ ~ =a ~ t o rJ 1 .. . .. . .. . .. . '- - ' " rJ 1 Z ~ "' d ~ 0 IIPA Data Request No 1.4 (f) (iii-v Non- Requirement Sales - MWh' f(iii)f(iv)f(v)f(vi)f(vii) LTF Intermediate SIT Qther IQtal Jan-045,542 104 932 288,686 782 919 Feb-866,009 153,601 104 834 651 089 Mar-934 017 196 030 749,469 526,470 Apr-959,471 140 072 958 209 518 332 May-720 011 142 862 065,607 497 640 Jun-763 003 140 536 902 092 461 757 Jul-949 642 158.687 001 304 163 161 Aug-992 186 193 321 515 080 182 359 Sep-050,419 168 163 987 021 157 221 Oct-028 474 158,968 075 218 100,515 Nov-999 561 150 512 966 695 134 975 Dec-087 995 160,887 264 882 271 562 Total 11,396 330 868 571 879 097 4,448 000 591 998 Jan-917 248 171 102 308 557 208 824 Feb-99 813,702 157 559 839 731 139 252 Mar-777 576 162,411 948 790 150 360 Apr-864 524 173 111 032,433 129,415 May-891 ,303 163 863 033 744 111 842 Jun-813 622 167 764 635 945 148,842 Jul-868,792 192 339 1,494 672 155,158 Aug-905,489 226 220 1,496,771 249 976 Sep-964 331 208 766 332 665 216 931 Oct-063 722 326 797 640 656 123 375 Nov-037 815 321 028 625 666 91,072 Dec-1 056036 184 555 1,456 281 144,444 Total 10,974,160 2,455 515 845,911 869,491 145 077 Jan-063.121 177,606 087 353 241,461 Feb-976,355 319 426 060,262 728 Mar-887,755 242 747 396,514 145 Apr-809,573 222 285 157 216 398 May-861,486 204 002 060 705 131 407 Jun-818,452 161 046 218 133 99,186 Jul-913 864 185 108 850 556 51,637 Aug-928 131 225,237 151,114 43,474 Sep-OO 908 334 196,522 295,536 139 Oct-931 209 224 976 786 244 791 Nov-897 712 218,507 958 262 37,097 Dec-835 714 198 789 319,187 072 Accrual adj 638) Total 10,831 706 576,251 341 082 022,535 (6,638)764 936 Jan-903 197 139,013 713 680 33,792 Feb-712 821 115 514 806,204 102 Mar-685 294 48,168 841,920 104 282 Apr-685 813 503 091 503 508 May-707 768 14,160 905 342 47,101 Jun-625 979 360 908 035 30,450 Jul-749,384 848 188,698 63,265 Aug-761,440 582 269,263 40,368 Sep-572,446 078 1,499,472 601 Oct-668,714 643 249,086 360 Nov-624 229 14,301 1,489 156 29,769 Dec-710.110 933 208 027 775 Total 8,407 195 486,103 13,170 386 577,373 22,641 057 IDAHO CASE NO. PAC-O2- ACIFICORP lIP A DATA REQUEST ATTACHMENT lIP A 1.4(g) Pa c i f i C o r p s R e s p o n s e t o I I P A D a t a R e q u e s t N o , 1 . g - ' mo n t h l y p e a k d e m a n d l e v e l s ' - M e g a w a t t s 19 9 8 Ja n , Fe b , Ma r , Ap r . Ma y Ju n , Ju l . Au g . Se p , Oc t . No v . De c . Co m p a n y - o w n e d g e n . 7, 4 3 7 71 4 76 5 82 6 50 5 56 6 93 7 80 8 06 5 61 6 55 1 75 9 ii - v . Pu r c h a s e s ( a ) 41 7 1 58 9 3 53 0 4 39 3 6 59 1 7 83 4 1 54 1 1 62 9 5 64 1 3 31 7 0 30 0 7 52 1 7 Ot h e r ( b ) 56 2 18 8 36 8 08 3 20 6 94 0 17 7 24 9 25 7 09 9 64 3 21 9 5 19 9 9 Ja n . Fe b . Ma r . Ap r . Ma y Ju n , Ju l . Au g . Se p . Oc t . No v . De c , Co m p a n y - o w n e d g e n . 66 6 80 0 84 4 73 2 30 7 83 1 74 9 11 0 13 9 92 6 16 3 32 2 ii - v . Pu r c h a s e s ( a ) 76 4 90 0 08 5 14 2 84 0 51 4 56 8 22 5 66 2 66 6 02 9 17 3 Ot h e r ( b ) 50 8 59 7 38 7 17 7 10 4 87 1 28 8 10 2 99 1 58 8 67 8 68 9 20 0 0 Ja n . Fe b , Ma r . Ap r , Ma y Ju n . Ju l . Au g . Se p . Oc t . No v . De c . Co m p a n y - o w n e d g e n , 63 4 31 1 64 2 84 4 6, 4 9 1 41 6 90 9 98 8 76 3 75 3 62 7 16 5 ii - v . Pu r c h a s e s ( a ) 07 4 61 8 04 9 09 2 42 8 23 4 00 5 90 7 98 5 67 0 22 8 80 7 Ot h e r ( b ) 68 1 20 2 97 6 34 4 93 6 33 6 03 5 02 5 00 0 17 4 92 4 50 9 20 0 1 Ja n . Fe b . Ma r . Ap r . Ma y Ju n , Ju l . Au g . Se p . Oc t . No v . De c , Co m p a n y - o w n e d g e n . 50 1 27 3 77 1 52 4 6, 4 3 9 14 8 70 9 6, 4 8 9 88 5 80 2 69 3 90 8 ii - v . Pu r c h a s e s ( a ) 91 6 22 7 56 8 79 7 91 7 15 7 79 5 88 0 55 3 74 4 46 0 38 4 Ot h e r ( b ) 52 2 49 4 01 4 91 2 88 6 86 1 07 6 02 6 02 5 05 4 69 5 1, 4 5 5 No t e ( a ) ; i n c l u d e s m e t e r e d a n d s y s t e m p u r c h a s e s . No t e ( b ) ; i n c l u d e s r e c e i p t s o f e n e r g y a s s o c i a t e d w i t h s t o r a g e a n d e x c h a n g e a c c o u n t s . PacifiCorplP AC- February 5, 2002 lIP A Data Request No. 1. lIP A Data Request No. 1.5: On page 4 lines 12-16 of Mr. Watters' testimony there is a discussion for meeting near tenn resource requirements; buy forward to cover the bulk of the requirements or rely upon the day-ahead and real time markets. Please answer the following: of two options that the Company had Please provide a copy of any memo, analysis, or communications that address the Company s review of these two options. What is the timeframe over which these options were reviewed and when were the decisions made as to what course of action(s) to take? Please defme what is meant by the statement "the Company could buy forward to cover the bulk of resource requirements." How (and to what magnitude) is this different or the same as the practices of the Company during the timeframe leading up to this period? Please define what is meant by the statement "or leave most of the balancing to the extremely volatile day-ahead and real-time markets." How (and to what magnitude) is this different or the same as the practices of the Company during the timeframe leading up to this period? F or each month considered, what was the anticipated cost, MWH and timing of any forward purchases that were reviewed? F or each month considered, what was the anticipated cost, MWH and timing of any day-ahead or real time purchases that were reviewed? For each month from January 1998 through the most recent month available, what was the MWH, dollars, and $/MWH associated with all "forward purchases ? Sufficient detail is requested so that the impact of the Company s decision to use "forward purchases can be quantified. A fonnat similar to Mr. Watters ' Exhibit 2 is requested. For each month from January 1998 through the most recent month available, what was the MWH, dollars, and $/MWH associated with Heavy Load Hours and Light Load Hours for all "day-ahead purchases ? Please provide sufficient detail so that the impact of PacifiCorplP AC- February 5, 2002 lIP A Data Request No. 1. the Company s decision to use "forward purchases" can be quantified. For each month from January 1998 through the most-recent month available, what was the MWH, dollars, and $/MWH associated with Heavy Load Hours and Light Load Hours for all "real-time purchases ? Please provide sufficient detail so that the impact of the Company decision to use "forward purchases" can be quantified. Response to liP A Data Request No. 1.5: There are no specific documents as requested. The Company rationale was as follows: Leaving larger quantities to balance in the daily and real-time markets was not felt to be advisable during a time of market uncertainty about regional resource balance due in part to the low level of hydro resources. Also, prices were expected to be sensitive to winter weather events. Placing large requirements into the marketplace can also have an adverse impact on market prices. The primary timeframe was the spring-summer period of 2000 through to July 2001. Options for covering 2001 short positions in the load and resource balance in advance of the Hunter 1 failure were reviewed beginning in summer 2000 and continued through the period in question. The statement "the Company could buy forward to cover the bulk of resource requirements , means that the Company could purchase standard products for a future period of time to cover a short position in load and resource balance. Buying forward was consistent with company practice prior to this period. The statement "or leave most of the balancing to the extremely volatile day-ahead and real-time markets , refers to buying or selling energy products to satisfy load and resource balance requirements, either one day ahead of the delivery period (day- ahead market), or one or more hours ahead of delivery in the day- of market (real-time). The California market allowed California utilities to balance only in these short-tenn markets. PacifiCorp did not believe it was prudent to fill the majority of its requirements in the short-tenn markets because ofthe extreme price volatility prevalent, but chose to use short-tenn markets only PacifiCorplP AC- February 5 2002 lIP A Data Request No. 1.5 to adjust for changes in resource balance. This was consistent with company practices prior to this period. It became even more important not to leave larger quantities to the short-tenn markets after market prices increased dramatically. As is referenced in Mr. Watters ' testimony on page 5 , lines 5- in the summer of 2000, the Company began purchasing energy to meet its expected energy requirements for 2001. This was primarily for the summer 2001 period, which had the largest balancing requirements and the largest potential for price variability. Exhibit 2 of Mr. Watters' testimony sets forth the energy purchased, cost of the purchases, and timing of the purchases. There are no forward markets for daily and hourly energy products, and price projections are limited to monthly blocks of energy. Infonnation regarding daily products does not become available until the delivery month, and infonnation for real-time products and prices do not become available until the delivery day. Forecast infonnation on day-ahead and real-time markets is not available. See Attachment lIP A 1.5(g). Data for 1998 and 1999 will be forthcoming. See Attachment lIP A 1.5(h). Data for 1998 and 1999 will be forthcoming. See Attachment lIP A 1.5(i). Data for 1998 and 1999 will be forthcoming. Witness: Stan K. Watters IDAHO CASE NO. PAC-O2- ACIFICORP lIP A DATA REQUEST ATTACHMENT lIP A 1.5(g) \.f '-' '-tI Done Date Done Date Month Year MWH Dollars MWH/Doliars Month Year January 2000 LLH 116 877 239 246 $2.1996 2,408 190 $23.1998 182 381 $15.1998 2,487 $0.1999 928 121,968 $20.1999 165 805 266 930 $19.1999 48,250 005 750 $20.2000 12,457 277 653 $22.2001 HLH 228,091 412 071 $1.1996 800 66,500 $23.1998 730 384 $18.47 1998 321 $0.1999 270 149,994 $20.1999 000 281 000 $28.1999 10,000 328 000 $32.1999 489 613 966 955 $22.40 1999 90,800 671,400 $29.42 2000 317 411 553 $22.47 2001 February 2000 LLH 118,469 198,148 $1.1996 069 49,139 $23.1998 573 40,705 $15.1998 1,478 $0.1999 934 101 ,907 $20.1999 765 765 $0.1999 192,400 296,070 $22.2000 800 178,500 $26.2000 21,735 489,038 $22.2001 HLH 196,404 319,096 $1.1996 788 66,215 $23.1998 4,428 81,943 $18.1998 211 $0.1999 729 139,182 $20.1999 10,000 281,000 $28.1999 993 327,770 $32.1999 59,285 94,160 $1.1999 '-_ 339,992 241 273 $27.2000 75,600 131,100 $28.2000 40,039 900,878 $22.2001 March 2000 LLH 116,096 163,486 $1.41 1996 065 49,044 $23.1998 737 43,299 $15.1998 813 $0,1999 813 93,440 $19.41 1999 156,000 3,483,870 $22.2000 60,000 1 ,442,700 $24.2000 32,448 730,080 $22.2001 HLH 263,201 349,918 $1.1996 912 69,160 $23.1998 918 90,862 $18.48 1998 205 $0.1999 035 119,762 $19.1999 10,800 303,480 $28.1999 10,800 354,240 $32.1999 375,200 10,829,200 $28.2000 214,000 282,460 $29.2000 44,928 010,880 $22.2001 April 2000 LLH 71,621 270,079 $3.1996 142 50,873 $23.1998 849 108,351 $15.1998 396 $0.1999 295 67,932 $20.1999 55,425 304,729 $23.2000 33,072 744,120 $22.2001 HLH 249,900 506,841 $2.1996 800 66,500 $23.1998 507 87,121 $15.1998 111 $0.1999 591 114,957 $20.1999 69,827 1,473,504 $21.1999 39,842 932,445 $23.40 1999 20,000 402,500 $20.1999 28,752 $0.2000 230,000 937,700 $34.2000 156,492 085,673 $32.2000 41,600 936,000 $22.2001 May 2000 LLH 143,934 263,119 $1.1996 296 54,530 $23.1998 949 109,933 $15.1998 311 $0.1999 3,499 71,913 $20.1999 105,800 576,980 $14.2000 69,212 670,296 $24.2000 HLH 250,600 635,389 $2.1996 912 69,160 $23.1998 975 94,525 $15.1998 849 $0.1999 234 107,580 $20.1999 72,800 536,600 $21.1999 41,600 973,440 $23.40 1999 104,000 905,800 $18.1999 546,748 17,396,274 $31.2000 218,946 823,661 $40.2000 June 2000 LLH 183,019 182,485 $1.1996 051 48,711 $23.1998 193 50,513 $15.1998 061 $0.1999 580 53,124 $20.1999 113,952 689,640 $32.2000 47,920 311,200 $48.2000 16,489 535,087 $32.45 2001 HLH 301,733 258,601 $4.1996 816 66,880 $23.1998 805 91,835 $15.1998 604 $0.1999 264 87,744 $20.1999 72,800 536,600 $21.1999 41,600 973,440 $23.40 1999 104,000 905,800 $18.1999 156,000 836,480 $37.41 2000 422,000 18,566,120 $44,2000 251,968 20,151,680 $79.2000 33,183 466,617 $74,2001 July 2000 LLH 183,019 182,485 $1.1996 051 48,711 $23.1998 193 50,513 $15.1998 061 $0.1999 580 53,124 $20.1999 113,952 689,640 $32.2000 47,920 311,200 $48.2000 16,489 535,087 $32.45 2001 HLH 301 ,733 258,601 $4.1996 816 66,880 $23.1998 805 91,835 $15.1998 604 $0.1999 264 87,744 $20.1999 72,800 536,600 $21.1999 41,600 973,440 $23.40 1999 104,000 905,800 $18.1999 156,000 836,480 $37.41 2000 422,000 18,566,120 $44.2000 251 ,968 20,151,680 $79.2000 33,183 2,466,617 $74.2001 August 2000 LLH 131,190 1 ,841 ,102 $14.1996 016 47,880 $23.1998 845 29,188 $15.1998 947 $0.1999 747 36,207 $20.1999 109,200 938,336 $45.2000 23,400 006,200 $43.2000 207,000 12,398,500 $59.2000 37,000 812,000 $76.2000 535 434,520 $57.2001 HLH 298,487 655,247 $15.1996 024 71,820 $23.1998 905 91,259 $18.1998 233 $0.1999 935 60,570 $20.1999 10,800 354,240 $32,1999 64,800 813,480 $58.2000 32,400 $0.2000 54,000 024,000 $56.2000 129,600 993,944 $61.2000 280,800 16,719,156 $59.2000 75,600 10,335,600 $136.2000 484,400 77,593,200 $160.2000 92,560 14,686,000 $158.2000 759 011,854 $130.41 2001 September 2000 LLH 122,680 824,038 $6.1996 240 53,200 $23.1998 666 27,118 $16.1998 123 $0.1999 670 58,416 $21.1999 111,100 022,269 $45.2000 24,000 1 ,032,000 $43.2000 64,000 904,000 $61.2000 128,000 364,000 $73.2000 27,200 040,000 $75.2000 256,665 350,784 $13,1996 HLH 800 66,500 $23.1998 335 62,929 $18.1998 749 $0.1999 729 103,074 $21.1999 10,000 328,000 $32.1999 30,000 470,000 $49.2000 30,000 $0.2000 20,000 080,000 $54.2000 120,000 7,401,800 $61.2000 257,542 15,357,645 $59.2000 20,000 190,000 $109.2000 170,000 21,595,000 $127.2000 342,400 45,743,400 $133.2000 112,400 17,177,400 $152.2000 October 2000 LLH 171,140 073,052 $12.1996 851 13,676 $16.1998 146 $0.1999 948 64,206 $21,1999 935 508,305 $103.1999 4,450 $0.1999 96,300 937,707 $40.2000 148,050 939,913 $67.2000 216,490 15,284,575 $70.2000 38,216 776,901 $72.2000 286 49,949 $21.2001 HLH 300,040 550,955 $8.1996 002 56,708 $18.1998 605 $0.1999 131 89,946 $21.1999 240 642,720 $103.1999 10,400 341 ,1 20 $32.1999 67,536 $0.1999 62,400 317,640 $37.2000 119,475 885,333 $40.2000 72,800 4,445,480 $61.2000 135,200 12,334,400 $91.2000 573,955 64,660,625 $112.2000 163,834 17,558,169 $107.2000 824 18,004 $21.2001 November 2000 LLH 170,639 911,292 $22.1996 625 10,257 $16.41 1998 120 $0.1999 298 269,304 $50.1999 800 494,400 $103.1999 10,045 $0.1999 650 874,439 $40.2000 128,000 388,000 $65.2000 24,000 1 ,992,000 $83.2000 121,579 674,834 $71.2000 59,117 194,932 $87.2000 \....; HLH 341,549 15,182,005 $44.45 1996 700 69,905 $18,1998 2,489 $0.1999 166 314,194 $50.1999 000 618,000 $103.1999 10,000 328,000 $32.1999 125,540 $0.1999 60,000 228,500 $37.2000 117,600 804,464 $40,2000 70,000 274,500 $61,2000 80,000 747,500 $71.2000 240,000 22,650,000 $94.2000 607,880 55,245,931 $90.2000 418,776 40,158,549 $95.2000 December 2000 LLH 175,297 3,445,538 $19.1996 1 ~029 16,710 $16.1998 610 $0.1999 604 358,408 $54.1999 888 895,480 $240.1999 16,473 $0.1999 100,133 093,311 $40.2000 137,600 017,100 $65:53 2000 25,800 141,400 $83.2000 20,115 1,420,301 $70.2000 214,550 17,645,250 $82.2000 415 714,381 $131.2001 HLH 335,244 13,798,059 $41.1996 709 51,157 $18.1998 212 $0.1999 865 423,952 $53.1999 992 114,000 $235.1999 10,000 328,000 $32.1999 126,147 $0.1999 60,000 228,500 $37.2000 114,376 678,459 $40.2000 110,000 384,500 $67.2000 80,000 747,500 $71.2000 30,000 880,000 $96.2000 63,404 064,324 $79.2000 703,098 107,585,878 $153.2000 58,400 31,174,400 $533.2000 475 767,214 $208.2001 Done Date Done Date Month Year MWH Dollars MWH/Doliars Month Year January 2001 LLH 222 346 278 124 $5.1996 537 630 $16.1998 143 858 $6.1999 302 290 $9.1999 780 $0.1999 400 $19.2000 090 414 541 $38.2000 581 1,409 336 $57.2000 800 598 150 $62.2000 68,268 257 613 $62.2000 57,400 671 950 $81.2000 22,494 5,480 056 $243.2000 33,652 682 924 $139.2001 $2.2001 HLH 330 906 754 132 $5.1996 104 393 $18.47 1998 660 960 $6.1999 659 64,495 $9.1999 129 968 $0.1999 2,473 160 $19.2000 10,400 431 600 $41.2000 79,255 084,887 $38.2000 930 942,073 $56.2000 600 984 800 $71.2000 732 037,987 $76.2000 800 839 200 $136.2000 173,427 48,737,403 $281.2000 144,825 26,739 548 $184.2001 February 2001 LLH 184,542 171 879 $6.1996 782 683 959 $170.1998 200 893,000 $220.41 1999 164 984 $6.1999 934 133 788 $38.1999 708 731 $9.2000 100 208,400 $57.2000 64,800 037,400 $62.2000 445 743,366 $61.2000 (...; 600 384 200 $64.2000 659 660 $16.2000 110 $0.2001 457 976 $45.2001 HLH 287 231 563,119 $5.44 1996 279 046 53,501 843 $191.1998 200 16,404 800 $268.1999 259 554 $6.1999 600 398,400 $41.1999 71,402 782 249 $38.2000 670 921 $9.2000 000 719 200 $56.2000 400 755 200 $71.2000 60,443 648 146 $76.2000 200 620 800 $136.2000 793 723 $18.2000 915 $0.2001 58,190 278 679 $211.2001 March 2001 LLH 177 787 380 969 $7.1996 398 22,466 $16.1998 450 700 $6.1999 573 565 $9.1999 632 326 015 $39.2000 23,400 341,600 $57.2000 70,200 373,850 $62.2000 64,247 043 085 $62.2000 23,400 1,499 550 $64.2000 438 104 $45.2000 854 874 $9,2001 920 10,400,360 $189.2001 000 432 000 $108.2001 HLH 337,756 008 491 $14.1996 2,480 865 $18.1998 2,412 14,472 $6.1999 173 920 $9.1999 800 448 200 $41.2000 159 036,093 $38.2000 000 059,100 $56.2000 200 099,600 $71.2000 700 612 570 $73.2000 600 948 400 $136.2000 582 932 714 $236.2000 774 4,492 824 $197.2001 108,448 294 944 $270.2001 50,000 110 400 $222,2001 April 2001 LLH 193,664 520 803 $7.1996 2,452 39,404 $16.1998 668 10,008 $6.1999 917 37,480 $9.1999 205 294 $16.2000 961 990 689 $32.2000 850 869,006 $59.2000 502 979 527 $59.2000 975 622 050 $78.2000 444 380 $45,2000 833 241 141 $133.2001 132,367 382 555 $259.2001 198 800 065 688 $191.48 2001 800 219 300 $124.42 2001 HLH 266,287 610;196 $21.1996 994 974 $16.1998 925 550 $6.1999 692 45,233 $9.1999 337 $16.2000 10,000 415 000 $41.2000 610 2,467,708 $33.2000 20,000 890 000 $44.2000 130,000 115 120 $54.2000 000 565 000 $59.42 2000 000 530,000 $76.2000 672 656,453 $51.2000 10,000 780 000 $78.2000 20,573 326 301 $161.2000 131,094 24,210 087 $184.2001 176,000 47,028 000 $267.2001 169 980 513 600 $250.2001 200 920,240 $260.2001 May 2001 LLH 104 720 275 145 $12,181 1996 124 133 $16.1998 1,464 784 $6,1999 230 30,636 $9.48 1999 250 115 511 $32.2000 200 949 950 $59.2000 34,465 032,474 $58.2000 200 639 600 $78,2000 341 652 $45.2000 286 304 169 $133.2001 560 852 800 $130.2001 200 824 500 $222.2001 272 619 616 $129.2001 HLH 230,415 274,543 $22.1996 583 369 $16.1998 510 060 $6.1999 050 255 $9.1999 400 431 600 $41.2000 825 688,308 $32.46 2000 800 925 600 $44.2000 135 200 291,440 $53.2000 400 707 600 $59.42 2000 800 591 200 $76.2000 650 687 375 $50.2000 10,400 811,200 $78.2000 21,317 3,455 730 $162.2000 115,542 20,820 929 $180.2001 720 328 000 $177.2001 000 12,474 800 $239.2001 132 320 894 517 $339.2001 79,472 22,336 216 $281.2001 June 2001 LLH 104,647 294 168 $2.1996 177 34,984 $16.1998 035 210 $6.1999 355 22,442 $9.1999 130 089 $16.2000 84,091 837 331 $45.2000 45,600 734 100 $59.2000 31,782 898 482 $59.2000 600 592 800 $78.2000 323 826 $45.2000 038 135,726 $133.2001 080 790,400 $130.2001 600 691 000 $222.2001 528 829 600 $81.2001 946 419,906 $52.2001 HLH 279,680 507 715 $8.1996 748 160 $16.1998 974 844 $6.1999 762 914 $9.1999 184 957 $16.2000 10,400 431 600 $41.2000 116,888 322 571 $45.2000 20,800 925 600 $44.2000 135 200 291 440 $53.2000 62,400 707 600 $59.42 2000 800 591 200 $76.2000 13,083 681 762 $52.2000 10,400 811 200 $78.2000 370 3,458,163 $161.2000 115,542 330,529 $184.2001 320 081,600 $130.2001 400 314 000 $222.2001 83,200 865,600 $383.2001 148,512 731,200 $341.2001 800 716,000 $195.2001 July 2001 LLH 120 716 605 086 $5.1996 627 26.146 $16.12'1998 022 132 $6.1999 185 20,559 $9.41 1999 14,400 844,208 $128.1999 585 373 504 $44.2000 600 567,600 $66.2000 575 092,325 $59.2000 35,709 145.759 $60.2000 600 670,800 $78.2000 288 13,219 $45.2000 88,605 516 315 $152.2001 880 894,400 $130.2001 600 204 000 $140.2001 101,650 703 650 $85.2001 800 516 400 $66.2001 \...I HLH 249,119 911 868 $7,1996 276 185 $18.1998 132 792 $6.1999 565 24,478 $9.1999 000 305,260 $128.1999 000 415,000 $41.2000 107 319 746,349 $44.2000 140,000 957,500 $99.2000 160,000 890 000 $118.2000 110 000 065 000 $146.2000 000 530,000 $153.2000 518 645 028 $56.2000 10,000 780 000 $78.2000 432 829 $45.2000 132 372 995 $264.2001 000 040 000 $130.2001 150 000 67,070 000 $447.2001 80,000 42,355 000 $529.44 2001 200,000 36,830 000 $184.2001 35,600 161 800 $60.2001 August 2001 LLH 114,687 563,393 $4.1996 512 298 $16.1998 513 078 $6.1999 188 11,456 $9.1999 636 105,667 $128.1999 92,044 3,469 339 $37.2000 800 514 800 $66.2000 800 806,050 $59.2000 883 941 162 $60.2000 800 608,400 $78.11 ' 2000 198 088 $45.2000 84,877 12,837,799 $151.2001 240 811,200 $130.2001 800 092,000 $140.2001 000 023,900 $90.2001 250 229,150 $57.2001 700 199,500 $35.2001 274 636,468 $39.2001 HLH 305,761 124 841 $10.1996 323 993 $18.1998 716 296 $6.1999 896 18,445 $9.1999 728 629 566 $128.1999 800 448 200 $41.2000 123 870 669,581 $37.2000 151 175 071,475 $99.2000 172 800 20,401 200 $118.2000 118 675 329 575 $146.2000 10,800 652,400 $153.2000 783 690,132 $58.2000 800 842,400 $78.2000 294 13,495 $45.2000 944 556,799 $256.2001 640 123,200 $130.2001 108,000 593 600 $459.2001 930 30,421,000 $564.2001 172,773 32,461 725 $187.2001 101 088 334 360 $82.45 2001 41,400 2,402,400 $58.2001 814 833,331 $39.2001 September 2001 LLH 122 308 555 549 $4.1996 1,430 604 $16.1998 144 864 $6.1999 531 095 $9.1999 10,727 376 381 $128.1999 94,465 167 186 $33.2000 8,400 554,400 $66.2000 50,400 021 900 $59.2000 981 096 872 $59.2000 8,400 655 200 $78.2000 171 849 $45.2000 235 13,291 444 $152.2001 720 873 600 $130.2001 8,400 176,000 $140.2001 83,925 7,488,975 $89.2001 200 259 200 $36.2001 80,823 086 032 $38.2001 HLH 246,643 2,401 858 $9.1996 742 33,285 $19.1998 219 314 $6.1999 790 26,639 $9.1999 13,483 730 004 $128.1999 600 398,400 $41.2000 \....". 104 050 516 622 $33.801 2000 134,400 399 200 $99.2000 153,600 134,400 $118.2000 105 600 15,422,400 $146.2000 600 1,468,800 $153.2000 986 618,521 $56,2000 600 748,800 $78.2000 181 308 $45.2000 749 537 303 $265.2001 680 998,400 $130.2001 96,000 083 200 $459.2001 000 072,000 $564.2001 144 000 27,705 600 $192.40 2001 86,400 153 600 $71.2001 38,400 324,800 $34.2001 152 324 274,103 $34.2001 October 2001 LLH 021 377 $1.1996 134 18,473 $16.1998 800 $0.1999 46,950 815 044 $59.2000 31,300 940 600 $62.2000 825 610,350 $78.00 2000 221 144 $45.2000 784 228 $9.2001 300 175 350 $69.2001 46,807 855 865 $18.2001 HLH 203,721 152 896 $0.1996 196 837 $19.1998 786 $0.1999 10,800 448,200 $41.2000 800 680,400 $63.2000 800 842 400 $78.2000 304 954 $45.2000 974 002,824 $121.2001 000 672 000 $68.2001 400 746 900 $53.2001 64,800 060 100 $31.2001 28,800 701 160 $24.2001 November 2001 LLH...J '--' 99,297 224 242 $2.261 1996 036 140 $16.1998 16,330 $0.001 1999 800 866,000 $59.96\2000 137 995 256 $60.2000 000 624 000 $78.2000 894 243 $9.2001 32,000 224 000 $69.2001 72,000 311 200 $18.2001 44,200 811 150 $18.2001 HLH 195,543 165,795 $0.1996 015 512 $19.1998 108,515 $0.1999 10,000 415 000 $41.2000 11,710 646 929 $55.2000 10,000 780,000 $78.2000 61,086 7,410 013 $121.2001 000 3,400 000 $68.2001 000 617,500 $53.2001 30,000 112,500 $37.2001 89,600 2,400,200 $26.2001 100,000 778,900 $27.2001 "-' IDAHO CASE NO. PAC-O2- ACIFICORP \wi lIP A DATA REQUEST ATTACHMENT lIP A 1.5(h) Done Date Done Date Month Year MWH Dollars MWH/Dollars Month Year January 2000 LLH 11,629 258,582 $22.1999 26,892 605,011 $22.2000 HLH 800 60,000 $33.1999 75,020 131 ,965 $28.2000 February 2000 LLH 800 18,600 $23.2000 18,946 479,628 $25.2000 HLH 10,169 279,599 $27.2000 129,963 826,750 $29.44 2000 March 2000 LLH 200 200 $21.2000 240 179 031 $22.2000 HLH 160 259,400 $28.2000 113 197 198,530 $28.2000 April 2000 LLH 11,267 264,386 $23.2000 131,160 982,676 $15.2000 HLH 5,440 178,180 $32.2000 58,601 784,100 $30.2000 May 2000 LLH 336 21 ,1 28 $15.2000 85,465 736,921 $32.2000 HLH 240 159,040 $37.2000 140,456 047,949 $57.2000 June 2000 LLH 803 203,047 $34.2000 103,000 261,101 $41.2000 HLH 11,520 779,099 $67.2000 230,770 41,820,155 $181.2000 July 2000 LLH 803 203,047 $34.2000 103,000 261,101 $41.2000 11,520 779,099 $67.2000 230,770 41,820,155 $181.2000 August 2000 LLH 600 37,800 $63.2000 97,1 25 11,535,465 $118.2000 HHL 820 735,785 $401.2000 141,020 27,921,587 $198.2000 September 2000 LLH 12,384 871,282 $70.2000 50,040 077,251 $81.2000 HLH 999 827,617 $82.2000 69,370 024,088 $130.2000 October 2000 LLH 080 778,720 $96.2000 45,515 849,201 $84.2000 HLH 517 697,825 $126.2000 105,905 10,841,863 $102.2000 November 2000 LLH 731 132,745 $76.2000 73,003 7,463,325 $102.2000 HLH 892 633,520 $91.2000 99,188 14,773,700 $148.2000 December 2000 LLH 914 461,387 $117.2000 38,448 346,673 $217.2000 HLH 788 710,997 $174.2000 89,509 32,539,799 $363.2000 '-' \.I Done Date Done Date Month Year MWH Dollars MWH/Doliars Month Year January 2001 LLH 120 284 000 $133.2000 233 880,073 $153.2001 HLH 232 855,427 $216.2001 650 301 608 $464.2001 February 2001 LLH 748 161 800 $216.2001 110 660 056 $169,2001 HLH 908 772 260 $265.2001 93,363 343 823 $239.2001 150 33,420 $222.2001 March 2001 LLH 609 109 030 $179.2001 737 840,625 $148.2001 HLH 861 407,795 $219.2001 80,427 297 312 $227.2001 April 2001 LLH 872 595,005 $207.2001 821 238 748 $178.2001 HLH 2,450 664 050 $271.2001 985 066,389 $240.2001 May 2001 LLH 5841 178 880 $112,2001 756 590 633 $137.2001 HLH 5,462 346 300 $246.48 2001 934 10,512 751 $233.2001 June 2001 LLH 500 482 300 $64.2001 20,075 937 561 $46.2001 HLH 815 364,615 $154.2001 341 146,413 $72.2001 July 2001 LLH 097 356,620 $69.2001 16,452 902,896 $54.2001 HLH 199 180 140 $81.2001 23,841 614 490 $67,2001 August 2001 LLH 120 $27.2001 018 539 954 $38.2001 HLH 280 575,540 $51.2001 102,158 875,898 $47.2001 September 2001 LLH 037 180 014 $22.40 2001 29,529 619 641 $20.2001 HLH 081 223 765 $27.2001 160 672 013 $27.2001 October 2001 LLH $0.1996 397 526 $11.40 1999 1,400 23,470 $16.2001 338 561 055 $24.2001 HLH $0.1996 958 $11.40 1999 259 129 780 $24.2001 157,692 551 288 $28.2001 November 2001 LLH 800 138,630 $28.2001 130 902 2,450,033 $18.2001 150 850 $19.2001 HLH 007 353,517 $35.2001 278,716 266 395 $26.2001 IDAHO CASE NO. PAC-O2- ACIFICORP lIP A DATA REQUEST ATTACHMENT lIP A 5(i) ..) Done Date Done Date Month Year MWH Dollars MWH/Doliars Month Year January 2000 LLH 110,323 387,722 2000 HLH 163,246 204,864 2000 February 2000 LLH . 74,339 715,521 $23.2000 804 $18.2000 HLH 134,573 3,418,202 $25.40 2000 March 2000 LLH 51,263 971,152 $18.2000 215 700 $21.2000 HLH 111,749 993,413 $26,2000 April 2000 LLH 64,489 012,397 $15.2000 920 $24.2000 HLH 103,311 2,471,259 $23.2000 May 2000 LLH 92,285 851,628 $30.2000 900 $30.2000 HLH 72,792 801,516 $52,2000 June 2000 LLH 112,640 051,831 $53.2000 110 600 $50.2000 HLH 209,910 28,813,579 $137.2000 July 2000 LLH 112,640 051,831 $53.6 '2000 110 600 $50.2000 HLH 209,910 28,813,579 $137.2000 August 2000 LLH 90,523 517,775 $83.2000 HLH 123,207 15,967,603 $129.2000 Septembe 2000 LLH 69,592 021,470 $72.2000 200 $25.2000 HHL 121,620 13,282,645 $109.2000 October 2000 LLH 72,202 973,205 $68.2000 HLH 104,172 664,105 $83.2000 November 2000 LLH 82,832 793,326 $118.2000 125 625 $5.2000 HLH 154,794 22,301 ,265 $144.2000 December 2000 LLH 83,315 16,261,040 $195.2000 HLH 91,751 22,012,146 $239,2000 Done Date Done Date Month Year MWH Dollars MWH/Dollars Month Year January 2001 LLH 118 717 896 934 $133,2001 000 $100.2001 HLH 188,585 635,742 $141.2001 February 2001 LLH 67,066 717,793 $159.2001 315 600 $166.2001 HLH 150,679 879 370 $131.2001 March 2001 LLH 44,178 832,376 $154.2001 110 500 $150.2001 HLH 543 182 740 $187.2001 April 2001 LLH 739 911 543 $145.2001 825 $135.2001 HLH 163 222 004 220 $189.2001 May 2001 LLH 87,053 706 815 $100.2001 162 200 $93.2001 HLH \...,t 138 807 541,797 $155,2001 June 2001 LLH 73,867 711 011 $50.2001 110 075 $73.41 2001 HLH 124 286 678,910 $69.2001 July 2001 LLH 45,444 915,519 $42.2001 295 300 $38.2001 HLH 058 570 771 $45.2001 August 2001 LLH 63,642 194 703 $34.49 2001 900 $18.2001 HLH 140,789 018,224 $42.2001 September 2001 LLH 556 165 647 $21.2001 HLH 67,239 518,659 $22.2001 October 2001 LLH 73,602 895 291 $25.2001 HLH 129 525 817 096 $29.47 2001 November 2001 LLH 47,614 813,871 $17.2001 HLH 76,061 796,732 $23.2001 PacifiCorplP AC-E-~ February 5, 2002 lIP A Data Request No. 1.7 lIP A Data Request No. 1.7: With respect to page 9 lines 11-17 of Mr. Watters' testimony, please answer the following: When was the sale of Centralia finalized? What was the monthly amount of energy eliminated because of the sale in 2000 and 200 I ? Response to lIP A Data Request No. 1.7: The consummation date of the Centralia sale was May 4, 2000. The amount of energy reduced related to the sale of Centralia would be the difference between the Centralia generation and TransAlta purchases. Such difference for the deferral period is calculated based on Widmer Exhibits No., 5 and 6 and provided as Attachment lIP A No. 1.7b. Witness: Stan K. Watters IDAHO CASE NO. PAC-O2- P A CIFI CO RP lIP A DATA REQUEST ATTACHMENT lIP A 1. At t a c h m e n t I I P A N o . 1 . 7b :MW b To t a l .I m fi b Ma r A9 r J. u n .w I AY 9 s. u .Q m No r m a l i z e d C e n t r a l i a G e n e r a t i o n 04 2 , 17 2 43 4 . 77 0 44 8 , 08 8 42 8 . 37 8 36 6 , 02 6 30 4 , 14 0 17 5 , 08 6 21 2 88 4 95 9 27 5 , 37 3 42 5 . 06 7 43 4 . 53 5 44 9 , 86 6 Ac t u a L T r a ns A l t a P u r c h a s e s 17 0 . 49 1 2. 1 2 . 2 5 Q 2M . 5 I 9 M1 . 5 5 O ll i . O Z 5 2O Z . 9 5 4 20 9 . . 8 0 8 ll i M l 2t M . 1 5 O 2M . 3 2 1 Di f f e r e n c e 87 1 , 68 1 22 2 , &2 0 23 3 , &0 9 28 6 , 82 8 23 9 , 89 0 18 3 , 88 4 39 , 42 1 85 , 80 9 (1 1 9 , 99 & ) 85 , &6 & 20 9 , 12 0 22 9 , 78 & 23 & , &4 & PacifiCorpIPAC- February 5 , 2002 IIPA Data Request No. 1. lIP A Data Request No. 1. What has been the monthly peak load and energy requirement for each month from January 1991 through the most recent month available for each of the following (please supply electronically and hard copy): The firm retail system load. The total retail system load. The total system load. The Idaho special contract load. The total Idaho retail load. Response to lIP A Data Request No. 1.8: a. For Total Retail System Load and Total System Load from January 1995 through December 2001 , please refer to Response to lIP A Data Request No. 1.14. b. This response has not yet been completed. We will submit it as soon as possible. c. This response has not yet been completed. We will submit it as soon as possible. d. This response has not yet been completed. We will submit it as soon as possible. e. This response has not yet been completed. We will submit it as soon as possible. Witness: Stan K. Watters IDAHO CASE NO. PAC-O2- P A CIFI CORP lIP ADA TARE QUE ATTACHMENT lIP A 1.8(a) "t:J ..... "0 ro E.Q :;:; 1ii 0) "t:J a. 0) E 1ii0) E 1;) :;:;;::... I1J CJ) 0) = ~ ro ro0) I1J ro .Q ~ * '5 0) ...E ~ :;:; c: ro E ~ ~ ro o I1J C- "t:J 0)c: ... ro 0)E E0) 0 "t:J I1J iD iD - - 0 0Z Z ex) ...... I1J ::s .c(a.. I1J I1J ... I1J ... I;::: a.. ro o - - I- ~ ::2.c: I ro "0 "t:J ro- 0....J - 00 o!!! ro.c: ... CJ)8 ex) ...... ...... ~ N ex) ~ ~ ~ ~ N ...... ~ m M ...... m 00 ~ ID ID N m N ID m ex)m ~ ID ~ M ex) ID 0 ...... ID ID ex) ~ m N m ID ex) ...... M ex) m ~ N ~ ~M M M M M ~ ~ M ~ M M M M M N M ~ ~ ~ ~ M M M M M M M M ~ 0 ~ ~$""" ...... ::2 "t:J ....J 0 ~ m 0 ID 0 M ...... ...... ...... ~ M M m ID ID ID ~ ex) ~ ex) ex) ID ~ ID ~ m ~ ...... ID ID ID N ~ ~ ~ ~ 0 0 M ID ~ N m ~ ~...... ...... ...... ............ ...... ...... ...... ...... ...... ...... ...... ...... ...... ...... ...... ...... ...... ...... ...... ...... ...... ............ E $~ 2 ~ .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c( .c(~-gzzzzzzzzzzzzzzzzzzzzzzzzzzzz CJ) .3 Cii O - - I- ~ E S0) ::2 I1J "0;::... ro CJ) .3 ~ M ~ ~ m ...... M ID 0 m ID N ...... ~ N ex) N ...... ...... 0 ~ ex) ID M ~ ~ ~ ~ M ~ ~ ex) M ID ~ ID M N m ex) ...... m ...... ID ...... N ID ex) ID N M ...... M ...... ~ m ~ ~ ...... ~ ~ ~ ID ~ 0 m 0 ~ ~ ex) m ...... ex) 0 N N ID 0 ~ ~~ ~ ~ ~ ~ ~~~~~ ~~ ~ ~~ ~~ ~ ~~ ~ ~~~ ~ ro O - - I- ~ ...... ~ ~ ex) ex) M N ~ ...... 0 M N ex) ...... 0 M ...... ID ~ ~ M M m N ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ffi g ~ ID ~ ro ~ ~ ID ro ~ ~ ~ ~ ~ ~ ~ ~ 0 S ~~~~roo~ri~~o~N~m~~~N~riro~riroO~N.c: ::2 ~ ...... M ...... M Nom ~ ...... M ~ ~ N N N ~ ~ ~ ex) ...... M M ~ ~ ...... M ro I NNNNNM~NNNNNNNNNMMMNNNNNNNNN "t:J "t:J ....J - 00 o!!! ro.c: ... O)-"t:J a. c:CJ)8 - E S~2::2I1J II- ;:..."t:JCJ) ~ ....J - = E S~~2::20) I1J II- ~ ;:..."t:J CJ) ~ ....J ...... m ...... N N ~ M N N M ~ ex) M ~ ~ ...... ID 00 ex) m m ...... 0 0 N~ ~ N ex) ~ ex) m ex) ~ 0 ~ M M ex) ~ 0 ~ ~ N ...... ~ 0 ex) ID m ID M5 ~ ~~ ~~~~ ~~~~ ~ ~~~~~~ ~~~~~~~~~~ ~ M ...... ~ M M ex) N ~ ~ ex) ~ ~ M ex) ~ m m N N ~ m ...... m ...... N m ~ ::2 ...... ...... ...... ...... m ex) 0 ...... ...... moo...... ex) ID ...... 0 m ...... ex) 0 0 ...... ...... ...... ...... ...... ............ ...... .............................. .................. ........................ ...... "t:J ....J ID ~ ID m m m ID ~ ex) M ex) N ...... m ex) ID M m N ~ 0 ~ N ~ ...... ex)m N ~ ~ ...... ~ M ID ~ m M N ~ M ~ 0 ex) ~ ex) ...... ~ ~ ~ N M ...... ...... M M...... m ...... NOM 0 ~ 0 m ~ ~ ~ ~ m M ~ N ~ M ex) M ~ ri ~ ~ ~ N ri ri ~ N ~ a ri ri ~ a ~ a ro ~ ~ a ~ ~ a ~ ~ ri ...... ~ 0 m ...... ~ ~ ~ ~ ex) M m ID ~ m ID m ~ ~ 0 ~ ~ M ex) ID...... ID M ...... ex) 0 ~ ~ ~ 0 ...... ~ ~ ~ ~ ex) N N ~ m ...... ~ ~ mom ~~~~~~~~~~~~~~~~ ~ ~ ~ ~~ ~~~~~~~...... ex) ~ M ID 0 M M N ~ m ...... N N m ID ~ ~ N m N ~ ID ex) ~ N N~ N N ~ m M ~ ~ ex) ~ ex) ~ ...... N ID N ID ~ 0 ~ ~ NO...... 0 ID N...... ex) ex) ~ N ex) M ex) 0 ex) ID m N ~ ...... 0 ~ M m ex) m ID ID M ...... mro~ ~o~ a ~ ~~NNm N m~ ~ ~ m ri ~m m ~ ~~mro~NN""" N mo...... MN ~m~MIDM......~""" M...... ID~Nex)~ ~ONN ~ ex) ~ ~ ~ 0 m ~ ~ ~ m ...... 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a ~ m ~ ~ ~ ~ ~ ~ ~ ~ N ~~~ ~~~~~~~~~~~ ~~~~~~~~~ ~~~~~~~~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z ~ m ~ ~ ~ m ro m ~ M ~ ~ m a ~ ~ ~ ~ m ~ ~ m m ~ ro ~ M N m ~ ~ N ~ ~ am M a ~ ~ a a a ~ ~ ~ ~ M ro ~ ro ro ~ ~ m 0 ~ a N ~ ro ~ ro N N ~ m N ~ ~~ N ~ ID M N ~ ~ m ~ ~ N a a M m ~ M ~ N N m ro M m ~ ro ~ ~ m a ~ ro m~ ID ID ID ID ID ~ ~ ID ~ ID ID ID ~ ~ ID ID ID ~ ~ ~ ID ID ID ~ ID ~ ID ID ID ID ~ ~ ~ m M ~ m M a ro M a ~ ~ m ~ a M M M m mOM ~ a ~ ~ ~ a ~ N 0 ~ m ~ ~ NM m M ro N ~ ~ m ~ ~ ~ M a ~ ~ a N m N ID ro M ~ N N ~ M ~ a m ~ ~ ~ ~ ~m ~ N ~ ~ ~ m m ~ ~ ~ N ~ a 0 a a ~ ~ ro N ~ N ~ ~ N ~ ~ ~ N ~ m M ~ ~00 ~ ~m m ID~ Nm ~~ N ~ ~ M N ro ~ ~M ~m room m ~ m roM ID ~M ro ~ ~ ~ M ~ ~ ~ NOM m m a ~ ~ ~ ~ ~ ~ ~ ~ N N ~ ro M M ~ M ~ ~ M MN N M N N N N N N N N N N M ~ M N N N N N N N N N N M M N N N N N N N ID a a ~ ~ m ro a ~ N ~ ~ M ~ M ~ ~ a m ro m ~ ~ ro ~ ~ m ~ M ~ m a ~ M~ M ro m ~ ~ ~ a 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For each month from January 1996 through the most recent month available, please supply the following:a. The total system load. Short-tenn finn purchases. Short-term fmn sales for resale. Non-firm purchases. Non-finn sales for resale. Any other data that would have gone into the Company calculation of "Net Short Tenn Purchases" as used in Table 1 on page 12 of Mr. Watters' testimony. Response to lIP A Data Request No. 1.9: The infonnation requested is provided as Attachment lIP A No. 1. Witness: Stan K. Watters IDAHO CASE NO. P AC-O2- P A CIFI CORP lIP ADA TARE QUE ATTACHMENT lIP A 1. At t a c h m e n t I I P A N o . 1 . 19 9 6 J. a n fi b Mi l : Am : .b m &I g Qc I To t a l S y s t e m L o a d 50 , 94 2 , 01 9 4 , 57 1 , 10 8 4 13 3 , 92 3 4 . 07 0 , 54 5 3 , 86 8 . 06 3 3 , 97 5 . 30 9 4 , 05 2 , 48 9 4 , 60 8 , 4 0 1 4 , 37 8 . 26 7 3 , 89 9 , 29 2 4 , 22 4 , 98 1 4 , 46 2 , 77 3 4 , 69 6 . 86 8 Sh o r t T e r m F i r m S a l e s 58 3 , 24 8 20 4 , 74 9 52 0 65 5 55 8 , 57 4 48 9 , 32 3 73 9 , 34 3 81 1 . 32 2 77 5 . 80 3 74 9 , 19 3 93 0 , 35 9 1 19 7 , 71 4 1 16 6 , 61 3 1 43 9 . 60 0 No n - Fi r m S a l e s 49 2 , 55 2 47 7 63 2 31 2 , 39 6 84 3 , 91 5 66 4 , 09 0 25 3 , 00 5 36 5 , 95 4 43 6 , 41 7 55 2 84 1 72 8 , 05 3 64 3 , 99 0 62 5 , 79 4 58 8 , 46 5 Sh o r t T e r m F i r m P u r c h a s e s 31 7 , 76 7 48 2 86 5 45 5 , 16 4 53 5 31 8 38 3 , 43 8 42 8 , 65 7 48 2 , 60 3 66 0 . 43 7 71 0 59 0 97 7 , 70 0 1 07 2 30 4 95 1 , 49 4 1 17 7 , 19 7 No n - Fi r m P u r c h a s e s 62 9 , 99 5 37 6 , 33 4 61 5 90 0 1 , 07 3 , 05 9 69 9 , 18 2 80 6 , 52 6 94 3 , 19 6 89 9 . 22 0 60 0 , 15 3 57 6 . 35 3 60 9 , 49 7 75 3 . 09 1 67 7 , 4 8 4 19 9 7 J. a n fi b Mi l : Am : Ju n Ju t Au g hI I Qc I To t a l S y s t e m L o a d 50 , 80 6 , 63 3 4 63 2 , 79 7 4 , 04 0 , 05 7 4 19 3 , 81 3 3 . 88 9 , 20 6 3 . 96 0 , 61 9 4 , 05 1 28 5 4 , 4 2 2 . 68 3 4 48 8 , 90 9 3 , 95 1 . 91 5 4 , 21 2 . 96 3 4 , 11 4 , 77 5 4 . 84 7 , 61 1 Sh o r t T e r m F i r m S a l e s 36 , 00 5 , 65 6 1 , 65 1 19 6 1 67 0 , 75 5 1 79 6 , 32 2 1 55 4 , 16 2 2 . 02 7 , 86 7 2 , 68 2 78 5 3 , 23 4 , 48 3 3 , 27 8 , 59 8 3 , 25 2 . 03 2 4 97 8 , 28 5 4 , 93 7 , 47 3 4 94 1 , 69 8 No n - Fi r m S a l e s 37 8 , 79 6 59 3 . 20 9 45 2 . 92 6 56 5 , 42 2 78 0 , 39 8 68 9 , 4 3 5 52 4 . 44 8 42 6 98 6 42 1 , 36 4 51 6 , 54 7 79 6 , 86 0 77 6 , 64 6 83 4 , 55 5 Sh o r t T e r m F i r m P u r c h a s e s 34 , 14 5 , 50 1 41 1 . 01 1 32 9 67 0 1 46 4 , 64 5 1 , 91 1 67 0 1 89 1 , 72 9 3 . 35 7 , 26 2 3 . 21 4 83 4 2 87 3 . 96 8 2 , 74 0 , 43 6 4 , 80 9 , 42 5 4 , 36 6 , 97 9 4 , 77 3 , 87 2 No n - Fi r m P u r c h a s e s 11 , 04 2 , 07 8 77 8 , 81 6 88 3 . 58 7 88 6 , 78 5 43 1 , 17 2 1 , 03 3 , 05 7 48 9 , 23 8 85 4 , 69 6 97 0 , 57 9 1 04 2 , 68 5 1 , 24 4 77 5 1 . 28 1 12 8 1 14 5 . 56 0 19 9 8 J. a n fi b Ma r Am : .b m Au g hI I Qc I tm ! .Q G To t a l S y s t e m L o a d 52 , 06 0 , 56 6 4 , 43 6 , 20 5 4 05 0 , 09 8 4 , 22 5 31 9 4 , 04 2 . 12 9 4 , 36 3 , 31 4 4 , 07 1 02 8 4 87 2 , 16 1 4 , 73 3 , 30 3 4 , 21 6 , 09 5 4 . 14 5 , 39 7 4 , 22 1 , 24 0 4 , 68 4 , 27 7 Sh o r t T e r m F i r m S a l e s 24 , 79 1 , 09 8 1 96 2 , 97 5 1 , 86 6 , 28 2 2 40 7 . 91 0 1 , 70 7 84 2 1 , 82 5 , 47 8 2 , 67 0 , 20 1 81 0 , 36 0 2 , 25 2 , 25 3 2 , 71 7 03 6 1 84 2 , 60 5 1 72 4 07 5 2 00 4 , 08 1 No n - Fi r m S a l e s 36 8 , 10 3 79 7 , 58 6 66 0 03 3 54 0 . 96 1 52 1 65 7 49 4 , 80 2 46 2 , 71 3 15 6 , 11 1 20 3 , 21 0 17 5 53 4 60 4 10 6 , 95 3 18 6 , 93 9 Sh o r t T e r m F i r m P u r c h a s e s 24 , 81 7 , 88 4 1 , 95 0 , 01 2 1 43 6 , 53 7 2 . 34 7 , 01 5 1 , 41 2 , 62 5 1 , 77 9 , 22 1 3 , 16 5 57 3 2 33 3 , 97 5 2 , 50 0 , 66 4 2 77 8 . 96 1 69 8 , 98 5 1 , 40 9 , 23 6 2 , 00 5 , 08 0 No n - Fi r m P u r c h a s e s 66 7 , 62 7 50 4 , 20 3 73 1 , 72 5 69 5 , 18 4 95 3 43 7 1 , 34 2 , 72 4 35 2 , 68 6 40 9 , 28 3 44 9 , 69 9 35 2 99 0 23 3 . 74 1 39 1 , 61 8 25 0 , 33 7 19 9 9 J. a n fi b Mi l : Am : .b m Ju t &I g hI I Qc I To t a l S y s t e m L o a d 51 , 18 4 , 94 6 4 54 8 , 01 5 4 , 16 1 01 0 4 23 3 , 47 9 3 , 99 8 , 30 3 3 , 81 2 , 94 2 4 07 7 , 61 0 4 , 63 3 , 49 0 4 , 54 8 , 22 2 4 . 01 9 , 25 7 4 10 1 , 03 3 4 26 6 , 43 1 4 78 5 , 15 4 Sh o r t T e r m F i r m S a l e s 18 , 01 8 , 17 3 1 93 1 02 3 1 51 8 , 70 8 1 59 0 91 0 1 69 8 , 61 3 1 86 2 , 20 7 1 , 48 0 , 17 4 1 30 6 , 98 8 1 30 3 , 67 7 1 14 0 , 4 1 0 1 , 44 6 38 5 1 , 46 2 , 32 5 1 27 6 , 75 3 No n - Fi r m S a l e s 56 1 , 46 7 21 3 , 84 9 14 5 , 12 2 11 8 , 21 1 11 4 , 52 2 65 , 72 0 12 1 , 62 5 13 6 . 22 8 22 2 , 21 2 17 5 , 75 8 39 7 75 , 16 1 98 , 66 2 Sh o r t T e r m F i r m P u r c h a s e s 18 , 07 4 , 53 2 1 54 5 , 76 1 28 7 34 4 1 . 69 7 . 78 2 1 78 1 . 05 1 86 4 , 4 0 0 1 , 69 2 94 0 1 , 4 9 0 , 66 1 56 0 , 26 8 1 09 4 , 29 1 35 9 . 51 6 1 51 7 , 23 5 1 18 3 , 28 3 No n - Fi r m P u r c h a s e s 20 7 , 63 3 31 6 , 19 5 26 2 35 9 24 6 . 95 7 51 3 , 82 7 33 6 , 46 7 25 8 , 65 6 17 3 , 16 4 13 6 , 96 6 24 3 51 2 28 4 , 72 2 22 2 , 43 4 21 2 . 37 2 20 0 0 J. a n fi b Ma r Am : J1 ! n Au g hI I Qc I tm ! To t a l S y s t e m L o a d 53 , 39 3 , 35 1 4 . 68 7 , 32 4 4 , 26 7 27 2 4 , 27 4 , 03 6 3 , 94 0 , 52 1 4 , 21 4 , 56 3 4 . 47 8 , 63 4 4 , 83 4 , 79 9 4 , 83 6 . 05 7 4 17 2 , 92 1 4 , 29 7 , 29 1 4 , 60 9 , 30 4 4 78 0 , 60 9 Sh o r t T e r m F i r m S a l e s 14 , 08 2 , 42 9 95 7 , 56 7 94 4 , 37 0 1 26 2 , 75 4 1 , 02 9 , 4 9 7 93 8 , 94 7 1 10 1 , 52 1 77 6 , 15 6 1 , 07 6 , 76 4 1 , 21 3 , 51 1 69 0 , 99 4 1 , 86 6 , 00 8 1 , 22 4 34 0 No n - Fi r m S a l e s 43 2 , 10 9 15 8 , 58 6 22 , 19 7 61 , 85 7 41 , 75 4 23 , 15 6 19 6 55 3 17 , 17 0 26 . 26 3 35 , 24 9 16 , 15 1 10 , 97 7 Sh o r t T e r m F i r m P u r c h a s e s 17 , 11 9 , 65 7 92 8 , 73 8 96 3 . 37 5 1 08 6 , 19 4 73 9 , 05 5 1 37 1 , 55 9 1 76 4 , 35 4 1 , 47 3 , 06 9 1 , 72 9 , 55 5 1 47 2 . 53 4 1 , 67 0 , 81 5 2 , 11 7 , 62 6 1 78 2 , 78 3 No n - Fi r m P u r c h a s e s 87 3 , 27 7 24 8 , 33 9 15 1 09 8 16 9 , 24 5 27 0 , 39 5 27 0 , 89 3 99 , 55 2 17 9 , 61 7 69 , 55 2 97 . 24 6 85 , 01 8 14 0 , 80 3 51 9 20 0 1 J. a n fi b Mi l : Am : .b i n Ju t &I g Qc I To t a l S y s t e m L o a d 66 9 , 27 8 4 78 5 , 77 6 4 , 27 8 52 0 4 . 30 8 . 52 3 4 , 10 7 17 4 4 , 34 5 , 91 4 4 28 9 , 32 3 4 61 1 , 32 8 4 69 1 , 00 3 4 . 18 5 , 09 4 4 . 14 8 , 34 3 4 17 0 , 91 8 4 , 74 7 , 36 2 Sh o r t T e r m F i r m S a l e s 12 , 21 0 , 23 8 61 8 , 03 5 71 9 , 76 6 74 6 , 20 4 1 00 9 , 30 3 83 0 , 96 6 83 6 , 03 5 1 , 11 4 , 29 8 1 , 22 9 , 42 3 1 , 41 7 , 15 8 1 17 9 , 86 6 1 , 39 6 , 35 6 1 11 2 82 7 No n - Fi r m S a l e s 30 7 , 74 2 95 2 07 8 35 3 18 . 85 2 36 . 73 1 14 , 99 9 36 , 39 4 16 , 04 5 30 , 84 2 42 , 28 3 18 , 69 6 31 , 51 7 Sh o r t T e r m F i r m P u r c h a s e s 14 , 31 2 , 36 6 1 , 12 4 , 23 4 1 , 05 5 , 48 6 95 3 , 56 3 1 , 52 8 , 03 1 02 9 , 49 2 1 01 4 , 50 9 1 43 9 , 88 8 1 , 59 2 , 08 8 1 49 9 , 89 2 85 3 . 35 2 1 10 5 20 9 1 , 11 6 . 62 2 No n - Fi r m P u r c h a s e s 87 2 , 77 8 33 1 33 7 16 3 , 86 5 15 2 67 8 85 , 48 0 19 6 , 72 2 18 6 , 83 0 14 7 , 51 1 16 4 71 3 42 6 ) 13 5 , 4 1 0 10 9 , 15 8 20 6 , 50 0 PacifiCorplP AC-E- February 5 , 2002 lIP A Data Request No. 1. lIP A Data Request No. 1.10: On page 13 lines 1-12 of Mr. Watters' testimony is a discussion ofthe Company mark-to-market value. Please answer the following:a. Please provide a copy of the analysis that detennined the mark-to- market value was $700 million on March 6, 2001. Please provide the results of all other mark-to-market analysis that were conducted by the Company between January 1999 and the present. If these analysis were conducted more than once a month then only provide the results of the first analysis conducted each month. What is the source and basis of "the then current forward price curve prices If not already included in "" above, on a monthly basis, what were the amounts (MWH and dollars) of all forward purchases on March 6, 2001 ? Please provide an explanation regarding how the anticipation of Hunter coming back on-line impacted forward purchases. Qualitative and quantitative infonnation is sought on how the expected restart date of Hunter impacted these decisions. Response to lIP A Data Request No. 1.10: The requested infonnation is confidential. The infonnation will be provided with applicable protections as soon as a confidentiality agreement is received from lIP A. No further infonnation is readily available.. The forward price curves are developed by the Company Wholesale Energy Services Department. Forward price curves are developed by averaging a number of market power quotes to buy energy at specific market hubs during specific periods from independent third party power mareketers. PacifiCorplP AC- February 5 2002 lIP A Data Request No. 1.d. The requested infonnation will be provided in the response to 10(a), which will be provided as soon as a confidentiality agreement is received from lIP A. Witness: Stan K. Watters Immediately after the Hunter Unit I generator failure, PacifiCorp began pursuing three different options for returning the unit to service. The most optimistic options estimated to return to service as of April I , 2001. The net position of the Pacifi Corp system reflected this return and April was about 100 aMW long for the HLH period on the date that the position first included the Hunter outage. In mid-December, PacifiCorp management made the decision to pursue the option of rebuilding the existing generator. The position was updated as of 12/26/00 to reflect a one-month extension of the outage to May 1 2001 for rebuilding the generator. With this update to the outage forecast, along with any other changes for the April position during the last month, the position for April was updated to about 400 aMW short. Approximately 300 aMW of HLH were purchased over the month of January to fill this short position for April. Hunter returned to service in early May. PacifiCorp/p AC-E- L...Tf'~February 5 2002IIp A Data Request No. 1.il\" 11 av IIp A Data Request No. 11: On page J 7 lines 4-5 ofM,-, Watters ' testimony there is a discUssion tha.c; SornetUnes We enter into near-term contracts... Please anSWer the fol:L sta When did this general POlicy Or activity begin regardin st1lJ1dard Product to meet the peak Deeds and then selling during the shoulder periods? ~he ::::nNiJ Please Provide any POlicy statements that qUality Or q activity.~tiPlease add sorne specificity and qUantification ~o sometimes . What percentage of days does this form represent? th~ What is the criteria for detenniJring Whether 1:his aC1:iv utilized versus not D:Iaking the Purchase of the s~and and then selling during the shoulder Periods?-t::y For each month :&om January 1999 through the .most; available . what Were the nll1nber of days this POlicy ""as meet peak? Response to lIP Data Reqnest No, 1, 11: There are no policy statements aVailable. The co U2pa..:..y- sujJer-peak and on-peak POsitions when Considering- r- =~fin deficiencies on a fol'Ward basis. SuPer-peak or sh--~~however , have limited liquidity, and the best altOInati ~~ ii11ing short-tern, deficiencies is often foTWard stand~c:::I. There is not a SjJeciJic definition for " SOmetimeswas g eneraJly refOlTing to the sllDnner period when .s....,. :IL produCts are differentiated in the market 11-010 on-peak During tlUs period there is a higher incidence of supe~ requirements tha" in other months. When foTWard On - products are PUrchased to aid in meeting suJ1er-Peak r~ ... -- SU1plus shoulder hoUr position may be Created. This -t:l Due to PacifiCorp' s shaped load requirements the P:raco't:i in/rocJUced when standard forward prodUCts beca.u e reo .at. available in the mid-1990' c;:::: c=:': ::r( .... ~:J1 ..7""'" :IJ ""1 :1."" PacifiCorp/P AC- ~- February 5 , 2002 liP A Data Request No. 1. lIP A Data Request No. 1.12: On page 17 lines 4-15 of Mr. Watters' testimony is a discussion of how the Company uses its "shoulder position . Please answer the following: Please explain the difference between the hourly market shoulder positions that are sold and non-finn sales. From January 1999 through the most recent data available please provide on a monthly basis a quantification of the Company anticipated shoulder position for future months. A fonnat similar to Watters' Exhibits 1 and 2 is requested, showing the expected MWH and dollars and how that expectation changed through time. From January 1999 through the most recent data available please provide on a monthly basis the actual shoulder position sold in tenns of MWH, dollars, and $/MWH. From January 1999 through the most recent data available please provide on a monthly basis the actual non-finn sales that were sold (MWH. dollars, and $/MWH) during the shoulder period that are not included in "" above. From January 1999 through the most recent data available please provide on a monthly basis the actual non-finn sales that were sold (MWH, dollars, and $/MWH) other than during the shoulder period. Please provide this infonnation on the basis on "non 6 x 16" times and "super-peak" times stated separately. Response to lIP A Data Request No. 1.12: The hourly market shoulder positions that were sold were the aMW which were surplus to PacifiCorp s requirements, within hours that are defined as the shoulder hours (hours 7-12 and 21-22). Non-finn sales are the aMW sold on a non- finn basis in any of the 24 hours. Shoulder hour sales sold on a non- finn basis are a subset of the total non- finn sales. See response 12 d. and e. for quantities sold. Please see Attachment 1.12b. PacifiCorp s position reports do not show a shoulder hour position. In October 2000, PacifiCorp s short-tenn position began to include aMW for the Super-peak period, and on-peak periods. From this data the requested MWh infonnation has been calculated for the shoulder hour positions. The attachment includes data for estimated PacifiCorplP AC-L. 1 February 5, 2002 IIPA Data Request No. 1.12 forward shoulder hour positions as of the first of each month. Please note that PacifiCorp s forward position changes with some frequency due to fluctuations in the portfolio element estimates; therefore not all changes from month to month are the result of forward transactions but may also be related to adjustments in generation or load forecasts. Because PacifiCorp s forward price curve has prices for standard HLH products only it is not appropriate for valuing the shoulder MWh shown in the attachment. This response has not yet been completed. We will submit it as soon as possible. This response has not yet been completed. We will submit it as soon as possible. This response has not yet been completed. We will submit it as soon as possible. Witness: Stan K. Watters ID AH CASE NO. PAC-O2- P A CIFI CO lIP ADA TARE QUE ATTACHMENT lIP A 1. At t a c h m e n t 1 . 12 b Pa c l f i C o r p E s t i m a t e d S h o u l d e r M W h T h r o u g h T i m e Ba s e d o n F i r s t of Mo n t h S h o r t . te r m P o s i t i o n s Mo n t h Vo o r Oc t - No v - 00 0 - 0 0 Jo n - Fo b - O I Mo r - Ap r - Mo y - Ju n - Ju ~ O I Au O - So p - O I Oc t - No v - 00 0 - 0 1 Jo n - Fe b - 0 2 Ma r - Ap r - Ma y - Ju n - 20 0 0 (7 3 , 71 2 ) 24 . 42 4 (2 9 . 84 0 ) 20 0 0 (4 3 . 70 2 ) (2 8 . 24 8 ) (1 8 . 64 8 ) 39 . 31 2 74 4 (5 0 16 0 ) 20 0 0 30 , 70 1 (3 1 84 0 ) 65 1 (1 8 , 05 5 ) (1 3 6 , 67 4 ) 20 0 0 (9 0 22 8 ) 37 , 64 3 40 9 07 0 20 0 0 (8 7 28 6 ) (9 1 , 47 2 ) (5 1 , 95 9 ) (9 2 , 88 2 ) (3 0 , 13 4 ) (6 7 12 1 ) (2 . 45 7 ) 20 0 1 52 6 (2 5 41 1 ) (5 4 , 58 4 ) (1 3 4 51 6 ) (2 3 . 75 3 ) 51 5 20 0 1 (4 , 81 0 ) (3 1 , 89 6 ) (8 0 , 44 9 ) (1 6 . 35 8 ) 11 2 , 84 9 20 0 1 41 3 (5 . 96 1 ) (2 8 65 2 ) 83 , 05 7 20 . 89 7 70 , 12 5 18 6 , 0 8 3 20 0 1 16 , 88 5 82 0 10 8 , 53 2 62 , 19 9 13 1 , 81 1 19 5 , 01 0 20 0 1 17 , 46 7 88 . 98 4 88 . 19 2 13 4 . 03 0 18 8 81 7 20 0 1 13 7 , 19 6 14 4 13 3 64 8 18 0 03 3 37 , 53 0 54 , 22 6 72 , 86 0 20 0 1 25 1 13 1 , 14 2 15 8 97 7 28 , 92 2 43 , 94 6 62 , 95 6 20 0 1 79 , 55 3 11 4 86 2 87 , 15 4 03 , 55 4 10 0 12 4 20 0 1 52 , 22 8 55 4 11 7 75 9 11 4 80 0 10 2 , 50 8 57 8 27 . 44 7 20 0 1 (7 8 99 5 ) 08 5 86 , 15 4 81 , 10 4 45 , 90 0 88 , 74 0 20 0 1 (2 5 , 55 2 ) 48 , 99 6 49 , 36 7 67 8 13 , 25 8 20 0 1 11 5 36 3 50 . 67 9 71 8 54 . 88 8 79 2 33 . 50 4 10 7 55 0 20 0 2 61 , 46 4 35 , 76 0 38 , 89 9 15 0 45 . 80 1 13 2 . 46 2 20 0 2 (7 7 . 17 0 ) (8 7 83 5 ) 67 4 ) 76 5 81 . 39 0 PacifiCorpIPAC- , . February 5, 2002 lIP A Data Request No. 1. lIP A Data Request No. 1.12: On page 17 lines 4-15 of Mr. Watters' testimony is a discussion of how the Company uses its "shoulder position . Please answer the following: Please explain the difference between the hourly market shoulder positions that are sold and non-finn sales. From January 1999 through the most recent data available please provide on a monthly basis a quantification of the Company anticipated shoulder position for future months. A fonnat similar to Watters' Exhibits 1 and 2 is requested, showing the expected MWH and dollars and how that expectation changed through time. From January 1999 through the most recent data available please provide on a monthly basis the actual shoulder position sold in tenns ofMWH, dollars, and $/MWH. From January 1999 through the most recent data available please provide on a monthly basis the actual non-finn sales that were sold (MWH. dollars, and $/MWH) during the shoulder period that are not included in "" above. From January 1999 through the most recent data available please provide on a monthly basis the actual non-firm sales that were sold (MWH, dollars, and $/MWH) other than during the shoulder period. Please provide this information on the basis on "non 6 x 16" times and "super-peak" times stated separately. Response to lIP A Data Request No. 1.12: The hourly market shoulder positions that were sold were the aMW which were surplus to PacifiCorp s requirements, within hours that are defined as the shoulder hours (hours 7-12 and 21-22). Non-finn sales are the aMW sold on a non-finn basis in any of the 24 hours. Shoulder hour sales sold on a non-finn basis are a subset of the total non-firm sales. See response 1.12 d. and e. for quantities sold. Please see Attachment 1.12b. PacifiCorp s position reports do not show a shoulder hour position. In October 2000, PacifiCorp s short-tenn position began to include aMW for the Super-peak period, and on-peak periods. From this data the requested MWh infonnation has been calculated for the shoulder hour positions. The attachment includes data for estimated PacifiCorp/PAC- February 5, 2002 lIP A Data Request No. 1. forward shoulder hour positions as of the first of each month. Please note that PacifiCorp s forward position changes with some frequency due to fluctuations in the portfolio element estimates; therefore not all changes from month to month are the result of forward transactions but may also be related to adjustments in generation or load forecasts. Because PacifiCorp s forward price curve has prices for standard HLH products only it is not appropriate for valuing the shoulder MWh shown in the attachment. This response has not yet been completed. We will submit it as soon as possible. This response has not yet been completed. We will submit it as soon as possible. This response has not yet been completed. We will submit it as soon as possible. Witness: Stan K. Watters IDAHO CASE NO. PAC-O2- ACIFICORP lIP A DATA REQUEST ATTACHMENT lIP A 1. At t a c h m e n t 1 . 12 b Pa c l f i C o r p E s t i m a t e d S h o u l d e r M W h T h r o u g h T I m e Ba s e d o n F i r s t o f M o n t h S h o r t . te n n P o s i t i o n s Mo n l h Vo a r Oc t - No v - Oo c - O O Ja n - Fo b - O I Ma r - Ap r - Ma y - Ju n - Ju ~ O I Au g - So p - O I Oc t - No v - 00 c - 0 1 Ja n - Fe b - 0 2 Ma r - Ap r - Ma y - Ju n - 20 0 0 (7 3 , 71 2 ) 42 4 (2 9 , 84 0 ) 20 0 0 (4 3 , 70 2 ) (2 8 , 24 8 ) (1 8 , 64 8 ) 31 2 74 4 (5 0 , 16 0 ) 20 0 0 30 , 70 1 (3 1 , 84 0 ) 85 1 (1 6 , 05 5 ) (1 3 6 , 67 4 ) 20 0 0 (9 0 . 22 9 ) 64 3 40 9 07 0 20 0 0 (8 7 , 28 6 ) (9 1 , 47 2 ) (5 1 , 95 9 ) (9 2 86 2 ) (3 0 , 13 4 ) (6 7 , 12 1 ) (2 , 45 7 ) 20 0 1 52 6 (2 5 , 41 1 ) (5 4 56 4 ) (1 3 4 51 6 ) (2 3 , 75 3 ) 11 , 51 5 20 0 1 (4 . 61 0 ) (3 1 69 8 ) (6 0 . 44 9 ) (1 6 35 8 ) 11 2 , 84 9 20 0 1 41 3 (5 . 98 1 ) (2 6 65 2 ) 83 , 05 7 20 , 89 7 79 . 12 5 18 6 , 06 3 20 0 1 16 , 98 5 18 , 82 0 10 8 , 53 2 62 , 19 9 13 1 , 81 1 19 5 , 01 0 20 0 1 17 , 46 7 98 , 98 4 88 , 19 2 13 4 03 0 18 8 , 81 7 20 0 1 13 7 19 8 94 , 14 4 13 3 64 8 18 0 , 03 3 37 , 53 0 54 , 22 6 72 , 8 6 0 20 0 1 98 , 25 1 13 1 14 2 15 8 , 97 7 28 , 92 2 94 6 62 , 95 6 20 0 1 55 3 11 4 66 2 15 4 93 , 55 4 10 0 , 12 4 20 0 1 52 , 22 8 55 4 11 7 , 75 9 11 4 , 80 0 10 2 . 50 6 79 , 57 6 27 , 44 7 20 0 1 (7 8 , 99 5 ) 06 5 86 , 15 4 10 4 45 , 90 0 86 , 74 0 20 0 1 (2 5 , 55 2 ) 48 . 99 6 49 , 36 7 20 , 67 8 26 6 20 0 1 11 5 , 36 3 50 , 67 9 71 8 54 , 88 8 79 2 50 4 10 7 55 0 20 0 2 61 , 46 4 35 , 76 0 89 9 15 0 45 , 80 1 13 2 , 46 2 20 0 2 (7 7 , 17 0 ) (8 7 83 5 ) (1 , 67 4 ) 76 5 81 , 39 0 PacifiCorplP AC- February 5 , 2002 lIP A Data Request No. 1. lIP A Data Request No. 1.13: Please provide a copy of the WUTC comments filed with the FERC on August , referenced on page 18 of Mr. Watters' testimony. Response to lIP A Data Request No. 1.13: An electronic version of the document is not available. However, attached below is a link to the FERC website. A hard copy is also included. http://rimswebl.ferc.feq us/rims.Q?ro PrintNPick Witness: Stan K. Watters PacifiCorpIPAC-E- . February 5, 2002 IIPADataRequestNo.1.14 liP A Data Request No. 1.14: For each month from Jariuary 1995 through the most recent month available please provide (in hard copy and electronic copy) the Company s Net Power Cost in a fonnat similar to Widmer s Exhibit 4 data that reflects: Actual data. . Type 1 data. Type 2 data. Type 3 data. Please provide a description of the differences between actual Type 1 , Type 2, and Type 3 data. Response to lIP A Data Request No. 1.14: The infonnation requested is not available for all years. The Company has only made semi-annual filings in Idaho for the 12- month periods ending December 1996 (Type I only) and 1997 (Types 1 2 and 3), and 12-month ending March 2001 (Types 1 and 3). For the periods when the Company did not make the semi- annual filings in Idaho, Net Power Cost studies were prepared for other jurisdictions. The Net Power Cost irifonnation that is available is provided as Attachment IIPA No. 1.14. Please refer to a. above. Please refer to a. above. Please refer to a. above. Actual Net Power Costs are the actual costs that the Company has incurred in a test period. Type 1 studies begin with actual data. PacifiCorp/P AC- February 5 , 2002 lIP A Data Request No. 1. Adjustments are made to nonnalize retail load, to remove the impact of temperature deviations, to nonnalize thennal generation to smooth the impact of fluctuations of outages, and to nonnalize hydro generation. Type 2 makes further adjustments from Type I which are called annualization. That is, if a known change occurred during the test period, the change is assumed to have occurred at the beginning of the test period. F or example, if the capacity or prices of a wholesale contract changed per contract terms during the period, such change is modeled to have happened at the beginning of the test period. Type 3. incorporates any known and measurable changes in the profonna period. Witness: Mark T. Widmer IDAHO CASE NO. PAC-O2- p A CIFI CO lIP A DATA REQ.UEST ATTACHMENT IIPA 1. ""'od-s""""",.. SfvdyP,.;od ended f213f/95 SPECIAL SALES FOR RESALE~ook ""s P". E SoCaJ EO"" 1'1 So c" EO"" (UI SMUD Si"". Pad"IPPSaI. Pugat P""" " Si"". Pad" II UMPAS". ""'ads lbas.,"",ads (P-no! APSSaI.APPA"'. CDWR"'.WAPA"'. WAPAII....pseo.... EWEB s". EWEB....95 Radd"".... AAahaOm ...."'....... "nson~.ok "U, Capaaly ~ack "U, S""". "'....."'" Sprin,""_'T"",",mP _t T"", ",m Inl.... _,T"", "'mU Sa=dIwy ..... _ads"'" eo-n,.,-""-1 SWln,,"'. TOTAL SPECIAL SALES PURCHASED POWER' NET INTERCHANGE BPA p-"" ......... BPA En""",..,1 C--ly BPA """""""" C_'ly ~ook "Us C--ly CoGanIJ"",.. Riv..Mi"",....b. OSPE""""'WNP", C.""'.... "'..,Lea..lyPGE..Co..IPCJ'aILmUSBR"'_"",P""'" "'" F. Con""". PPOlWNP""""'.'m TnSla1a ...-. MPC PURCHASE 1990 Swth ldahol Utah to""""""'.. Swth '_I BPAto P",,", Swth '_I S".... Sooth '_I R_nol S""'" APS ..."'os. Tn SIB'. Ex- SCE ..."'os. STF ...-.. """"atBPAEx- WNP ...-. 1994 WNP Ex- ",,"SIBIB GSLM aF Con.",Ia. UPOllOP ......,. Blac' "'IS ...-. B""'....."",Radd""..._. CoC3an/Hoom','on SBOa1daoy ...-.. TOTAL PURCHASED PW & NET INT WHEEUNG' U. OF F EXPENSEBPAln"".0.... TOTAL WHEELING' U OF F EXPENSE THERMAL FUEL BURN EXPENSEC""",. D....J"""""Jlm"',"'-Wy-C.stn. C.....,N_"", -""'"'"-,..~""'" Chell. ",., Hayden GadsbyH..ml,"'" TOTAL FUEL BURN EXPENSE NET POWER COST Nst p""", ""'.No! Syst"'" Load P",", ~ann"" 0212012002 I'" AM "8.367 131.043 222141 222,141 546834 833,820 23,138200 445, 427783 534849 15,600,887 053,993 043427 933423135377 420,985 052172 52,036869 324000 452,365 15,204,849 750000 580,600 141 503580 22,160159 858, 697984 32,5&5,213 PO""""'", . NeI p""" """AMy., III AcIUBJ 1995 498,367 131, "'" 222,144 222144 546834 833,820 23,138,200 39,445888 21,427783 534,849 15,600,887 421 043427 933423 29,135377 420,985 052,172 52,036,869 324000 452365 204,849 750,000 580600 141 503,580 22,160,158 1.858,899 40,897984 '87,571 320,888 798,432 539494 28,959 Typal 1995 20,"8,367 131043 222,144 222,144 548834 833,820 23,138,200 095,952 21.427,783 890, 800,887 421,946 043427 933423 29,135377 420,985 052,172 52,036,869 324000 957171 398708 750000 872,000 180,000 286693 616,514 679,166 19,375,225 979,303 079,764 088,550 809,329 8TO Typall f995 Type III '998 21,573.451 489,433 489433 489745 18,612,355 23,309 027623 21,6TO,992 837776 835,352"4,200 9TO,793 424,278 994998 42,589942 23,974 326,423 198,3&9 405,248 825000 550250 536,800 f80,OOO 120000 536065 501.8" O86' 599271 16,311148 653,214 194 229,808 582,212 ---- 483,998,438 979000 90,389 90,389 030566 &63,821 562.734 366989 770236 215820 167226 630532 273.820 "', 152 534000 321802 689955 (271656) (37 "') 386840 724151 405603 109,528 (60027) 131,205 612,432 23,138200 388, 759115 32,390328 482,468,755 77,979,000 90,3&9 90,3&9 030,566 863,621 13,662,734 366989 28,770,236 215820167226 630,532 273,820 "', 152 534000 321802 669964 (271656) (37 "') 386840 17,724151 14,405603 109,528 (60,027) 131.205 19,612,432 23,138,200 388,889 759,115 22,494242 441489,790 80,256,000 85,824 85,824 1.030,566 13,562,734 440436 28,573571 317,685 167,226 630532 791,415 40,8",152 to,534000 321802 669964 (271656) (37499)386840 724151 405603 109,528 (60,027) 131,205 612,432 138,200 5tO, 612222 776,502 471TOI366 80,266,000 181 181 140,000 to,227685 13,8",239 689,737 059104 317885 185278 868,107 866, '" 975,890 896672 209.427 (251344) 282,588 040187 444580 317,820 '" , 844 131,205 22,059,445 23,731309 899,998 707.475 824069 615507 560,928 ---- 342,122,310 332,226,223 381037 45,054,374 45,054,374 45,415,411 332,611100 994 45,054,374 45,057,368 64,3&9657 43,608382 325 854337 029,869 932,428 694, 636599 80,856,339 367,525 37,663,262 12,145572 ,", 1'" 22,073735 663231 608382 906666 854337 99f801 932.426 48,878,035 636599 80,619,440 367,525 147835 12,1714281'" 19,450,389 366764,875 66,62& 52,914,480 991,106 715,914 732135 481771 910106 693283 964,673 46,663,058 44,763,977 80,435,324 379,729 053, 12,193092 412217 19,575,813 14,104,761 ---- 456,830,334 45,739324 "'7 663 890898 819296 211555 188221 394313 369167 222,918 205,043 604598 12,545,977 948,822 16,243,851 475,627695 487826,260 481.074,041 360,008,580 m........ .-------... ..-....... '_._n__'.- 8... 390800,574 403824938 419108664 .-.--...... ..--..... ....n..... ........... 7.40 797 823 AIIB,'"PADRf 14.,. 1995 S."".-S""I' P""....... '2131195 NET SYSTEM LOAD SPECIAL SALES FOR RESALE Block 1"" PG&E SoCII """"IP) SoC" """'(U) SMUD So"".P"""IPPSoi. PugoI P- "So"".P""'", UMPASoi.-"'(",".1-"'(P-... APSSoI. APPASoi. CDWRSoI. WAPAS". WAPA"SoI. PSCoSoi. EWEB Sol. EWEBSoI...R_noSoi. Aneheim Sol. """'Sol. 1'""", Block 1"', C--~ BI"'" H",S'",... "'......""" "",ngttodstKrtT.... A"" P stKrt Toom Arm ",..,. stKrt T.... A"" U_Sol" -.......""'...,........., SWln'..'.Seo- Losses 646,327 3532'" 252,790 508,055 SO8,O5S 350,400 512.794 215,245 051.200 45'900 886 438015 158112 386,350 118865 613,200 136, 564339 157192 110205 398622 367300 105 65,435 057342 116,348 189,961 430,591 PD"""'S"' .... p"".. """ E...., -,.. (MWH) ""'"" '995 054,805 353,230 252,790 508.055 508.055 3SO400 512,794 215245 051200 45'.900 30,686 438015 160112 3863SO 118865 613.200 1,"868 564339 157192 110.205 386.622 387300 '05 65.435 057342 118 "'" 189861 712.268 T,pel 1995 054.805 3532'" 252.790 508.055 508,055 3SO.400 512794 215,245 051200 458.900 886 438015 160112 386.3SO 118865 613,200 . 1 38, 868 564.339 157.192 326,403 372,301 876000 195.535 530.'16 38.783 116,504 880,086 308,518 340,617 38.038 000 095 T,pe" 1995 T,pe'" 1996 49.054.805 37982'2 614880 614.880 3SO400 608.212 318924 05'922 461213 138 437948 197640 392653 114,765 833.845 '84.840 560286 159498 373.321 373321 905,760 SOI600 30.000 327855 210240 530176 38,783 '16,SO4 850.485 421.404 301.033 123708 ISO 33.791 403164 304269 111019 033 TOTAl SPECIAl SALES ---- 83.425304 15.1",475 421.152 13.149,364 370499 "-""'" .-..-... .-.-..... ..=....-.= TOTAl REQUIREMENTS PURCHASED POWER & NET INTERCHANGE BPA P-no PIx-. BPA _......tsi "-'~BI""'H","-,~ CoGenIJ..." ""'.. ..dC""",;.C........En"""", OSPE_dWN,,' CoIook"" "'enL"""~ PGE.-eo.. IPC........., USBR "'_nosPo"" ""'eoF """."",. PPOl WWP PIx_. 1989T.Slel. PIx"'... MPC PURCHASE 1990S_ldeholUtah '.Gosh...",... Sooth ldeho I BPA to P","', Sooth ldeho I SI",... Sooth ldeho R..... " S""'" APSPIx""""TriSleleEx- SCEPIx"""" STFPlxohaes """".. BPAEx- WWP PIx_. 1994 WWP Ex- GemSIeIeGSLMOF"""""",. UPOlIPPPIx_.BI""'H", PIx_. BPA""""""'"R_ngPlx"""" CoGenIHerm'"",_PIx_.. 83,785,802 (294) 31.032 115477(46,669) 228761 578. (170.432) 600 23,916 (60,351) 185 62.954 477764 438,000 66',253 600 (846,525) 846415 33.577 (33957) (3,409) 354.980 SO7473 2001SO) 82'2 285 418461 215245 165 84.432 739589 62.415957 (294) 032 262.235 (46.889) 228161 576326 (170432) 600 23.916 (6035') 185 62,954 477764 438.000 889.253 87.600 (846525) 846415 33.577 (33,"7) (3.409) 364,980 SO7473 55,200 'SO) 822 81.285 418.461 215,245 38,165 84.432 62,204.159 .........- ........... 261911 (46889) 228781 516.326 (170.432) 87,600 23.816 (60,3511 185 86.184 477.784 438,000 669253 87.600 (846.525) 846415 577 (33957) (3,409) 354,980 SO7473 55.200150) 822 285 418461 215.245 452184 131837 551.454 443,063 269,259 (43,697) 221.189 283.536 (178.188) 600 043 (72,680) 300 421 458011 289872 285481 '8357'211 835.711 31,418 (31515) 439 972 827.410 283520 109298 43. 184 4373SO 318924 589998 1463SO J32.198 280 930332 TOTAL PURCHASED PW' NET 'NT ---- 994 COAL ARED GENERA TICN"""'0'.D"".J-ten JIm en....w,-CoI"'p c'""""_ten -,""""_,.. BI""'" """,. er., Heyden ......"ten Trq... 168884 089.811 958,956 387115 008,284 994601 352.883 772.109 810471 324.268 742 707 1.284,484611330 637451 (827) 719739115845 058518 228,271 909.744 222.009 015.945 663034 101,318 190389 594 205.253 552876 886 293772 484.948 115845 048.232 228,271 905,453 1.222.009 006.'60 663.034 077.602 190389 279.980 207819 552, 763360 519.980 "8,552 193,371 998,875 530 871631 225.436 988211 882048 059135 190,921 274. ISO 209,969 564.316 768,281 480 TOTAL COAL ARED GENERATION ---- 48,512908 SYSTEM HYDRO .,.,.... ",... "'an "'an S""'" 004325 2786SO 785 888.530 005 900,948 (2.481) 917738 342 TOTAL RESOURCES ---- 63,425304 TOTAL SYSTEM HYDRO -- ~......ng 02/20I20O2 11 49 AM 83,785,802 812,593 9",535 898.918,080 82,415.957 .........- ........... 62.20415' ........... """"'" "Iao. "PA DR 1 14 ," - '995 ~d System SemI Annual Study Period ended 12/31196 SPECIAL SALES FOR RESALE 81"'* Hills PG&E So Cal Eelson (P) So CaI Eelson (U) SMUD SIerra Padfic IPP Sale Puget Power II SI""" Padfic II UMPASaieNe- (base) Nevada (Peaking) APSSaie APPASaie CDWR Sale WAPA Sale WAPA II Sale PSCoSaie EWEB Sale 95 Redding Sale AnaheIm Sale Clark Sale Hinson BI",* Hills Capacity 81"'* Hills Storage Glenbrook Springfield ESI-Kalser PNGC Cheyeme Sale Deseret SUpplementalOk~an UMPA II Sale Plains electric G&T Short Term Arm P Short Term Arm Intertie Sholl Term Arm U 5econdery Sales Neveda FOU' Comers Nor1hwest SWlnlertie TOTAL SPECIAL SALES PDlMac SIucIy Results Nel Power Cost Anelyols ($) Actual Type I Type II Type 111 1996 1996 1998 1997 930985 930 985 20,371,853 414082 (82.440)(82,440) 41,376,227 20,666,115 21,854692 24,696 033 20,666 115 21.854,692 24,696,033 539,824 539,824 469.744 431,200 757,451 757 451 17,927,995 18,241,146 534 751 534,751 25,534,751 933 025 41.792,828 41,782,828 42,535.244 872 020 22,865 241 22,885241 22,882,802 24.073 443 833.803 833,803 877,767 404,474 15,660,445 15,680,445 15.849.585 15,798.301 850,828 850.828 774.055 670,784 18,446,446 18,446446 17.246,761 17.513,451 425343 425,343 854,172 803.993 30,352,948 30,352,948 30,850,246 30,592,821 746,829 40,746,829 40,746,829 31.242,004 368,759 23.368,759 24,214,679 23,634,652 48,308.053 48.308,053 48.308,053 703 006 472,433 472,433 825.677 661.491 13,311,418 13,311,418 12,624,666 12.948.462 882.963 882,963 825,000 900.000 25.939,287 25,939,287 28.909,463 31,840,827 11,538,548 11,538.548 15,356,180 15,312.480 300,000 (170451)(170451)120,000 120,000 937,165 937.185 937.165 7.494,665 495,107 495,107 495,107 650,269 934,072 934,072 206,233 13,487.840 635.663 835,663 265,810 500.520 23,856,253 72,417 72,417 182.378 182.378 580,022 611,128 142,532 257 367 138 502,548 58,057,343 57,342,448 342.448 630765 248.191 248 191 69.614438 418 630 416,630 103 518,978 952 398 23,702 598 985.326 766,182 240.384 884,587 831,438 726,170 788,752 787 663 17,488,837 026.495 548 915 267 227 265,492 666,108.465 598,541,666 616,183,552 848,900.697 PURCHASED POWER & NET INTERCHANGE BPA Peeking Purchase 76672,000 BPA enUUement Capacity 1 034 143 BPA SUpplemental Capacity BI",* Hills Capacity CoGenIJames River Md CoIlI11bia CSPE Hanford WNP #1 CoIock\.m GranL c.....ty PGE Cove IPC Rellm USSR Greensprings F. Contracts - PP&L WWP PIrchase 1989 TriState Pt6chese South Idaho Utah 10 Goshen Area South Idaho BPA 10 Padfic South Idaho Storage South Idaho Rellm of Storage APS PIrchase Tri Slale Exchange SCE Pt6chese STF P\.rchases Deseret BPA Exchange WWP P\.rchase 1994 WWP Exchange Gem Slate GSLM OF Contracts - UP&L IPP PIrchase BI",* Hills SLIp/us BPAGlenIJrooI( Redding Pt6chese CoGenIHermiston Deseret DesereI Monlhly Power Planning 02/2012002 12:31 PM 159 907 14,120 142 848 110 13.402 182 166932 184313 017368 47,798283 898,698 19,577481 (210 184) 12,477 265,839 392612 127,473038 11,338,206 067,200 (45850) 333,197 058,238 21,025,077 25,534,751 997521 707475 884,961 41.423 154 175 997 672,000 095 75,095 883,953 159.907 14,120 142 948 110 402 182 166 932 184,313 017,386 47.798,283 13,898,898 19,577,481 (210,184) 12,477 265,839 392 812 127.473 038 11.338.206 067,200 (45,650) 333,197 058.236 21,025.077 25.534.751 997.521 707,475 884,961 41.423,154 175.997 73,920,000 220 71,220 883,953 18,177,892 120,142 709 524 188932 184,313 017386 47,798,283 13,898,666 11.107,016 (210,184) 12,477 265.839 392 812 122,889 367 11,338,206 067.200 333,197 058,236 21.025.077 25.534,751 997,521 707475 635 006 63,984,800 14,104.115 920.000 248 69,248 005.840 18,694,883 120 142 674,901 188,932 169265 770 953 48,802,988 936 200 10,856,123 (296,196) 174,929 238.493 523,409 122,889,367 12,351,600 376,476 333.197 873.458 20.626.206 23,933,025 415,520 707.475 702,325 84.243,497 27,820,467 Page 1 AI1ach IIPA DR 1.14-,ds -1996 ee-et ExpansIon 913,349 913349 192,039 581.582 Deseret NF PI.n:ha8e 332 912 332,912 931 385 348.670 APS Exchange Secondary 97,611 949 33,891,989 909 575.753 TOTAL PURCHASED PW & NET INT.582.967.652 499.017692 503.161.587 512.293,970 WHEEUNG & U. OF F, EXPENSE BPAInl8ftie 492622 326,407 313.262 550.155 Other 55.679361 55,679.361 576 973 65.664,960 TOTAL WHEEUNG & U. OF F. EXPENS 372.003 58.207.789 65,690.255 89.215.115 THERMAL FUEL BURN EXPENSE Centralla 64.658,429 105,275 713.971 229.057 Dave Jo/'nston 36.263406 36.907.613 907.613 797.703 Jim Bridger 65.789564 89.117.663 005891 302,010 262,066 19.972,472 19,972.472 19,916.053 CoIsbip 320,153 258933 273.146 6,473.597 Carbon 976.459 904448 904.448 682:JT7 N".,q,ton 61,532.795 162,836 58.264,406 484936 Hlnington 46,891,216 046 252 42,046 252 928 144 HLI1ter 77,227 134 81,426,747 81,594.154 508.958 BILI1deII 595 447 215.647 215.647 206.894 ChoIla 21,745 634 32,664 308 939,228 29.032,559 Cnig 209 763 11.957 303 11,957,303 11.923 167 Hayden 603,433 367 145 454.650 413 725 Gadsby 467,944 648 854 155.641 155 641 Hemiston 106 255 14,259 466 32.342,688 32,254.320 TOTAL FUEL BURN EXPENSE 469687,720 473.055 382 481,747,900 461 509 161 ----------- ----------- ----------- ---------------------- ----------- ---------- ---------- NET POWER COST 400898.910 429736974 434,616.170 411 117.549 ---------- --------- ---------- --------------------- ------- ---------- --------- Net Powsr CosIINeI System Load Aferged System PDIMac Study Power Plsming 02l2Ol2OO2 12:31 PM P_2 Attach IIPADR 1.14.x1s-1998 Semi AmusI Sludy PMod ended 12/31/96 NET SYSlEM LOAD SPECIAL SALES FOR RESALE Black Hills PG&E So Cal Edson (P) So Cal Edson (U) SMUD SIerra Pacific IPP Sale Pugol Power II SIerra Pacific II UMPASaie Nevada (base) Nevada (Peaking) APS Sale APPASaie CDWR Sale WAPA Sale WAPA II Sale PSCo Sale EWEB Sale 95 Redding Sale Anaheim Sale Clark Sale Hinson Black Hills Capacity Black Hills Storage GlenIIrook Springfield ESI-Koisor PNGC Chey..... Sale Dosorot SupplementalOk- UMPA II Sale Plains electric G& T Short Term Finn P Short Term Finn Intertle Short Term Finn U Soconda'y SaI.. Nevada FOIJ' Comers Northwest SWlntertie Secondary Losses TOTAL SPECIAL SALES TOTAL REQUIREMENTS PURCHASED POWER & NET INlERCHANGE BPA Supplemental Capacity Black Hills Capacity CoGonIJem.. River Mid CoIlOnbIa Canacian Entillomont CSPE Hanford WNP #1 CoIocWn GranLCounty PGE Covo IPC Rellm USBR Groonsprings F. ConIracts - PP&L WWP Plrchase 1989 TriState Plrchase South Idaho Utah 10 Goshen Area South Idaho BPA 10 Pacific South Idaho Storage South Idaho Return of Storage APS Plrchase Tn Stale Exchange SCE Plrchase STF ",""as.. Desorot BPA Exchange WWP l'IRhasel994 WWP Exchange Gem State GSLM QF Conlracls - UP&L IPP l'IRhase Black Hills Plrchase BPA GlortJrook Power Plaming 02/20/2002 12:31 PM Nel Power Cosl Energy Analysis (M'lVH) Actual Type I Type II Type III 1996 1996 1996 1997 50.942,019 50,771,528 50,771,528 881,201 330,280 330,280 330.280 328,501 084,217 542.111 835 258 813,200 542,111 835 258 813,200 350.400 350,400 350.400 350 401 550,948 550.948 550,948 587.401 340,214 340,214 340,214 318,888 049,444 049,444 049,444 094.620 463.858 463.858 463,858 459.901 34,998 998 998 800 438,875 438,875 438.875 438000 158,115 158,115 158,115 158 112 403845 403.845 403,845 388488 129,599 129,599 129.599 163,296 614.880 814,880 814.880 813,200 104,978 104,978 104,978 854 095 584,581 584.581 584,581 588 450 158,388 158388 158.388 158 320 337.425 337,425 337425 324,120 373.874 373,874 373,874 372301 185 185 982,784 982,784 045870 370087 501,878 501,878 887880 885780 (16 701)(18 701) 345,095 345,095 345 095 325855 280.855 280,855 280,855 216288 330000 330 000 438,000 876000 103,099 103 099 184 383 198 312 914 380 333 333 12,076 078 409 472 318 375,574 583,248 210.387 485,804 485,804 809,498 493,010 493,010 763,385 745038 745.038 492,552 842.708 522791 005440 93,22&83,044 55.741 201.110 255,995 123.885 513.844 082499 799,579 21,384 222 18,429 344 031 026 28,089,839 22.419800 21.881.483 23.137,208 ----------- ----------- ----------- --------------------- ----------- ----------- ----------- 79,011,858 73,191.328 72,853,011 72,996,409 ----------- ----------- ----------- ---------------------- ----------- ----------- ----------- 319 881 858,592 (44 206) 218,292 279000 (133,508) 87,800 24,024 (90,785) 81,217 496.289 289.873 543,713 (82) 000 24.149 10.791 317.787 284,486 82.800 150) 80,805 49,380 483,183 340,214 176,850 148,350 091 837 254 319,881 235.011 (44206) 218,292 279,000 (133,508) 87,800 24,024 (90,785) 81,217 498,289 289,873 543,713 (585854) 585,792 26,273 (26,273) 1,000 24,149 10,791 317,787 284.486 82,800 150) 80,805 49,380 483,183 340,214 178,850 148,350 441,853 234,254 (44206) 218 292 (133,508) 87.800 024 (90,785) 81,217 496,289 289,873 278,924 (585,854) 585792 273 (26,273) 000 24.149 10.791 342,405 284,486 82,800 150) 805 49,380 483.183 340.214 176,850 148,350 441.853 228,516 (41 876) 212,340 (183,587) 87,800 24,000 (74 132) 88,339 540,245 144,541 284701 (739 877) 739855 37,025 (37,879) 10,805 21,500 45,881 342,405 282,800 82,800 48,278 43,832 440,254 318,888 41,552 148,350 Page 3 Attach IIPA DR 1.14."s -1996 Redding FVd1ase 127108 127.108 127 108 130.000 CoGenIHenTioton 273.105 273105 681.920 681,920 Oeseret Annual 240.068 240,086 950.172 572 905 Doserel Monthly Deseret Expansion 91,398 398 219358 191 857 Deseret NF FVd1ase 286,084 268 084 530559 423,423 APS Ex"'-(44,140) Secondary Pu'chases 629 995 058,369 079.688 367,157 TOTAL PURCHASED PIN & NET INT.539 194 19,343.987 18.450,635 877529 COAL FIRED GENERATION Centralla 972,786 702,901 547 839 581 239 Dave Jomston 958,080 071 330 071.330 054 146 Jim Bridger 908635 10,209,440 984,766 883,214Wy-276898 183,118 183,118 178 951 CoIolr1p 795052 818,330 707,201 729 786 Carbon 411 250 232,005 232005 228 585 Naughton 080,911 413 525 500029 517.667 H.nIngion 408,988 726 281 726,281 707. H...ter 086.054 410,725 428,016 419,218 Bhnlell 191,912 171,895 171,695 171,217 Cholla 388,808 093,594 853,704 859 882 CraIg 358,518 344,827 344,827 340,990 Hayden 537 468 585,236 593,281 589519 Gadsby 155,593 231,505 231 505 231 505 Homioton 772,440 774.550 758 800 752,000 Trojan (545) TOTAL COAL FIRED GENERATION 46,280,836 969,084 312 397 49,243098 SYSlEM HYDRO Systam Hyao 191.826 885602 898,804 878,736 Draft From Storage (7,325)(8,625)(954) TOTAL SYSlEM HYDRO 191,626 878 277 889979 877.782 ----------- --------- ---------- ---------------------- ----------- ----------- ----------- TOTAL RESOURCES 79,011,858 191 328 853 011 72,998409 ----------- --------- ----------- --------------------- ----------- ----------- ----------- Power Ptanring 02l2OI2002 12:31 PM Page 4 Attach IIPA DR 1.14."0 -1986 Merged System Semi Annual Study Period ended 12/31/97 SPECIAL SAlES FOR RESAlE Black Hills So Cal Edison (P) So Cal Edison (U) SMUD Sierra PacI1Ic IPPSaie Puget Power II Sierra PacI1Ic II UMPASaie Nevada (base) Nevada (PoaIcIng) APS Sale APPASaie CDWR Sale WAPASaie WAPA II Sale PSCo Sale EWEB Sale 95 Redding Sale AnaheIm Sale Clark Sale Hinson Black Hills Capocity Black Hills Storage Glonbrook Springfield ESI-Koisor PNGC Choyemo Sale Doseret SUpplemental Okanogsl UMPA II Sale Plains Electric G&T Springfield II Cowlllz-BHP Clark-FW Clark-5EHA Clark-WT H..ncano Sales Short Term Ann P Short Term Ann Intertie Short Term Ann U Soconda"y Sales Nevada Four Comore Nor1hwost SWlntortie TOTAL SPECIAL SALES PD/MaC Study Net Power Cost Analysis ($) Actual Typal Typall Typalll 12/97 12/97 12/97 12/98 351 732 19,351,732 19,558,758 15,550,416 796,000 24,398,002 398,002 25,911 067 24,398,002 24,398,002 25,911 067 489,747 489,747 431,203 904239 17,881,819 881 819 900 110 330,322 955,202 955,202 27,955 202 25,542,717 985,875 985,875 43,888,144 45,071,830 153.285 24,153,265 24,073,548 25,394417 414411 414,411 484,184 798 603 883,712 15,883,712 794,768 109 040 070,848 070,848 885,129 833 784 406,944 17,406,944 072595 072,585 028979 380,888 30,817,592 30,817,592 30,592,688 30,192,013 857,849 32,857849 499,057 30,461,032 478,252 24,478,252 24,386,802 23,278,302 47,143,812 47,143,612 47,788,907 47,593,972 448,821 448,821 859 173 343,428 12,981,808 981,808 597,285 12,840548 908,150 908,150 38,289,985 38,289,985 454 599 20,808598 14,431,488 14,431,488 431 488 12,205088 390,734 390,734 390,734 285,000 (8,398)398)398)980 208,848 208 848 208 848 442,140 297,550 297,550 481 088 822,511 13,487,840 13,487 840 487 840 487,840 970,213 970213 970213 427,758 24,056,886 056,888 058888 157,932 117,248 117248 611,128 611 128 811 128 701,382 142,850 142850 142850 488,578 813,481 813481 357285 298353 288,340 288,340 518,675 524035 172,101 172 101 814,457 814,451 284,235 284,235 506,953 843823 773 295 773 295 518,333 389858 971 971 310 018 383,653 892 692 957 125,092 750,733,927 150,150,121 138 553,485 144,132,284 195,438,881 154 017,898 168 112, 405,145,125 321,981,386 338 770 474 139080,518 473,880 503,998 17,913,238 730 176 080290 349,454 488501 394,052 785,238 254,124 962,883 031,851 879 88,993 746895 406 206,122 275819,290 111,854,996 148,989,073 PURCHASED POWER & NET INTERCHANGEBPA Poalcing Pwchaso 73,920 000 BPA EntiUemont CapacIty 1 100,497 BPA SUpplemental Capacity Black Hills Capocity CoGonIJIIT1OS RIver Md CoIlniJIa CSPE CoIockIm Gra"CCOII'Ity PGE Cove IPC Relum USBR Greonsprings F. Contracts - PP&L WWP P\rchasel989 TriState Pwchaso South Idaho Utah to Goshen Area South Idaho BPA to PacI1Ic South Idaho Storage South Idaho Rolum of Storage APS Pwchaso Tri State Exchonge SCE Pwchaso Doseret BPA Exchonge WWP Pwchaso 1994 WWP Exchonge Gem State GSLM aF ContracIB - UP&L IPP Pwchaso Black Hills SUplus BPA Glonbrook Redding Pwchaso Power PlirI1Ing 0212012002 12:32 PM 15,287,849 758,459 843.888 088000 227.938 011,778 50,519,382 067 800 10,492.278 27,802 49,085 142,373 138.878 12,383.588 553.956 81,050 158.579 883,083 22,404,885 27,955,202 852,022 707,475 2.518,883 920 000 246 89,246 982,005 287,849 758459 843,688 088,000 227938 011,778 50,519,382 087,800 10,492,278 802 49,085 142,373 138,878 12,383,588 553,958 81,050 158579 883,083 22,404,885 27,955202 852,022 707,475 518,883 920,000 828 828 962,005 17,345,745 13,758 459 588184 068,000 227938 011,778 117,444 10,492276 802 49,065 138,678 553 958 158 579 883,083 22,331,107 955,202 852,022 707,475 122,878 73,920,000 82,067 62,087 958,839 17,944 297 15,447,220 289,304 088 000 193159 888557 50,439,850 10,990,883 (388,316) 514 427,189 712,248 303,915 873 458 22,331 107 25,542717 858,388 707,475 095476 Pagel Attach IIPA DR 1.14.xls -1997 CoGenIHennioton 738,988 55,738988 65,759,798 834447 Dooeret 25,324,988 324988 033152 875078 Dooerot Monlhly Deoerel ExpanoIon 787 680 787,680 787680 253,228 Dooerot NF Pu'chaoe 227 496 227,496 227,496 813,100 APS Exchonge HlJTicono 239 23,239 34,883 853 Clerk $&I 090,082 090082 STFPIrchaseoPPL 877111,888 384489,912 306588,255 324,422,518 STF PIrchaseo UPL 312,841,774 242457 233 253,889,300 Seconday 189739,783 70,272,477 088437 29,892,818 TOTAL PURCHASED PW & NET INT.223729544 104,262 238 939,117,402 985 873 932 WHEEUNG & U. OF F. EXPENSE BPAlntertio 844,959 984,181 493 832 71,808 Other 873,812 873,812 918 327 74,890,388 TOTAL WHEEUNG & U. OF F. EXPEN 518 571 70,657793 72,412,159 74,782,196 THERMAL FUEL BURN EXPENSE Centrella 884,481 86.570,892 86,080,810 008,328 Dave Johnoton 903,784 424,147 35,424 147 424,105 Jim Bndger 542,810 940,819 088543 80,804,203Wy-19,343 786 991,514 991 514 19,991,514 CoIob1p 572 770 818,890 883298 853 815C.oon 358 165 988170 988,170 988 170 N8IJ!j1Ion 82,831 680 53,918509 53,877497 998 861 H....tinglon 40,501,011 42,211,054 939320 42,939 232 Hw11er 72,789 828 74,154411 154,411 74,154411 BJInIeII 557 811 708078 708,078 708 055 Cholla 103 440 37,702 830 35,752,832 294 132 CraIg 12,327255 586 567 11,586,567 586 587 Hayden 379382 186 208 179,583 182 758 328389 680 579 750,870 483 818 Hormioton 23,888884 32,039 842 33,132,494 132 491 TOTAL FUEL BURN EXPENSE 481,891 438 484,860 306 484,095,932 485,308 080 ---------- ------- --------- ------------------ -------- -------- ------- NET POWER COST 389933429 384,381,047 383 770,497 378 755 115 ----------- --------- ---------- ------------------ -------- --------- ---------- Net Power CostINet S)'OIem Load 728 Aferged SysIem PDIMac SIudy Po- Plarring 02J20I2002 12:32 PM Page 2 Attach IIPA DR 1.14Jdo -1997 SemI Annu8I Study Pflfiod endsd 12/31197 NET SYSTEM LOAD SPECIAL SALES FOR RESALE Black Hills So CaI Edson (P) So CaI Edson (U) SMI:ID SIerra Pacific IPP Sale Puget Power II SIerra Pacific II UMPASele Nevada (base) Nevada (Peaking) APS Sele APPASaie CDWR Sale WAPA Sale WAPA II Sale PSCo Sale EWEB Sale 95 Redcing Sale AnaheIm Sale Clerk Sale Hinson Black Hills Cepadty Black Hili. Storage Glenbroolt Springfield ESI-Kaiser PNGC Cheyeme Sale DesereI SUpplemenlaiOk~ UMPA II Sale PleinsElectricG&T Springfield II CowIllz-BHP Clerk-FW Clerk-SEHA Clerl,-WT HInI"""" Sale Short Tenn Arm P Short Tenn Arm Intertle Short Tenn Arm U Secandery Sales Nevada F.... Comers Northwest SWlntertie Secandery Losses TOTAL SPECIAL SALES TOTAL REQUIREMENTS PURCHASED POWER & NET IN"TERCHANGE BPA SUpplemenlai Capacity Black HIli. Capacity CoGenIJemes RIver told CoILrmia CanadIan EntIaernent CSPE CoIodcIm GranU:o.I1Iy PGE Cove IPC Rel!An USBR Greenapringa F. Conlracla - PP&L WWP PIRhase 1989 TriSlate PIRhase South Idaho Ulah 10 Goshen Area South Idaho BPA 10 Pacific South Idaho Storage South Idaho Rel!An of St~ APS PIRhase Tri Slale Ex~ SCE FVchaae Desaret BPA Exchange WWP Pu-chase 1994 WWP Exchange Gem Slate GSLM QF ConIracIa - UP&L Power Planing 02l2OI2002 12:32 PM Net Power Coat Energy Analysis (MWH) Actual Type I Type II Type III 12/97 12/97 12/97 12/98 50,808 833 50,788,873 50,788873 50,788,873 409983 409 983 409,983 282,800 158,88&578,437 578,437 473,040 578,437 578,437 473040 350400 350,400 350400 350,400 542782 542,782 542,782 528,951 540399 540,399 540 399 385,288 051 200 051,200 051 200 1,010,880 459,908 459 908 459 908 459.901 43,755 755 43,755 181 437482 437,482 437,482 438,000 171 417 171,417 171.417 158,112 485 597 485,597 177.953 177,953 177 953 183,29& 813,218 813,218 813,218 813,200 &82,778 &82778 882,778 792,225 800,188 800 188 800,188 558 974 181,851 181,851 181,851 158 320 308 700 308,700 308,700 324 120 371,418 371,418 371,418 372.301 800 800 442195 442,195 028,&95 902,085 827458 827,458 827,458 530858 870 870 870 (130)(130)(130) 400378 400,378 400378 108180 188 145 188,145 188 145 210240 878,000 878,000 878.000 878000 181 831 181,831 181 831 187923 927011 927,011 927 011 952,389 307872 307,872 472 40,472 40,472 449 325 325 325 418 414 800 414,800 414,800 332 380 73,200 200 145,385 145 787 074 074 183,813 183 813 081 18,081 873 105,120 078 53,078 380828 438,000 444 444 79,597 221 239 239 211 485 38.005,858 475,338 578,798 578 798 10,047,489 083513 083,513 17,482,849 809089 14,809,089 378 798 380,587 339883 855,355 227240 118,829 124,852 105758 83,883 145072 908 145084 531,333 179 588 199 13,484 339 12,899 58,704040 51,885,819 45.812,899 44,957,884 ---------- ----------- ---------- ------------------- ---------- ----------- ---------- 109,510 873 102,472.492 98,399 372 744,337 ----------- ----------- --------- -------------------- --------- ----------- --------- 805 300 305 380,852 228 388 (41 870) 209,590 (188 198) 800 24,000 (122,519) 75,&82 518,248 148,920 273,838 488 513,244 518 410 12.943 284,174 82,200 550 87,938 32,737 490,704 305 409987 228014 (41 242) 207,844 (188,198) 87,800 24,000 (122519) 75,&82 511,088 273838 488 513,244 518 2,410 200 938 737 489,379 409,987 227,958 (37 002) 190,783 (158 713) 87.800 24.000 (90,552) 421 511,088 284.701 (474.970) 848485 788 (20,077) 138 (1) 800 455 &32 489,379 380 852 994 548 (41 989) 210 235 (188,198) 87,800 24,000 (122 519) 75.&82 518248 148920 273838 598,228 410 12.943 284 174 200 550 87,938 32,737 490,704 Page 3 Attach IIPA DR 1.14. ". - 1997 IPP-540,399 540 399 540,399 385 286 Black Hills 214,879 214 879 214,879 307 002 BPA Glenbrook 146,350 146 350 146,350 146350 Reddng 124 159 124 159 124,159 149000 CoGenIHenriston 981 877 961,877 1.881 922 861,922 Deseret AmuaI 440 099 440,099 773326 961,433ee....t Mon1hIy Deseret ExpansIon 170,024 170024 170,024 227933 ee....t NF IVchase 398,484 398,484 398,484 398,484 APS Exchs1ge HUTIcene 357 357 717 485 Clark S&I 139355 139 355 STF P\Rhages PPL 145501 21,030,201 854 260 17,854 260 STF P\Rhages UPL 115 300 232,086 232,088 Secondary 042,078 120,373 628,805 2,117 627 TOTAL PURCHASED PW & NET INT.55,245225 551\,837 41,527,822 858,904 COAL ARED GENERATION Cenlralla 382,223 858 162 829,749 825443 Dave Jomston 083,494 972,420 972,420 972413 Jim Bridger 786,354 961 043 998,793 842,596 Wyodak 299,922 155,484 155,484 155,484 CoIsb1p 019,592 696,724 902,786 901,455 CIIbon 1.405 087 203,801 203801 203,801 Naug,ton 089 286 616 290 595627 623,324 H.-,tinglon 142,185 851 254 786008 785 HUTter 717,335 234,861 234,861 234861 Bt.mell 168 520 175,855 175 855 175,854 ChoIla 433 537 478,850 350,844 517726 CraIg 385 293 343 557 343,557 343 557 Hayden 583,845 579 702 579,081 579 379 181,488 203 863 199,262 187 241 Henriston 961,743 861 001 861,001 861 001 Trojen (485) TOTAL COAL ARED GENERATION 519,219 50,032 707 49,988,951 009 949 SYSTEM HYDRO System Hydro 748,234 879071 879,442 879 785 Draft From Storage 877 157 301) TOTAL SYSTEM HYDRO 746 234 882948 882,599 875,484 ----------- ----------- ----------- -------------------- ---------- ----------- ----------- TOTAL RESOURCES 109,510 678 102,472,492 96,399372 95,744,337 ---------- ----------- ----------- --------------------- ----------- ----------- ----------- Power Plenring 02120/2002 12:32 PM Page 4 AItach'UPA DR 1.14."s -1997 Melged Sys/8m PD/Mac Study Semi Sludy Net Power Cost Analysis Period ended 12/31/98 ($) Type I Type II Type 111 12/98 12/98 12/99 SPECIAl SALES FOR RESALE Black Hills 474.275 162.020 734378 So Col Edison (P)30,081.662 081,662 24.591.387 So CaI Edson (U)30.081.662 081 662 24,591 387 SMUD 029040 937,936 438 645 Sierra Pacific 17,789861 17.925.290 343 737 IPP Sale 27.762553 27,762.553 27.084 186 Pugst Power II 067395 374 818 070.813 Sierra PocI1Ic II 410.622 408300 25.736.552 UMPA Sale 794,706 858402 854.550 Neveda (base)818.075 105440 179.858 Nsvods (Peaking)10,105.853 APSSoIs 889 546 APPASale 875 385 CDWRSale 243 799 30.232 975 184314 WAPA Sale 731 180 30.731 180 884 179 WAPA II Sale 927,504 927 504 511,455 PSCoSale 189.299 521 888 48.412.312 EWEB Sale 95 521.875 762,175 853 805 Reddng Sals 12.582.12,358.521 12,578442 Clark Sale 29.393,879 30,219.879 21,627 999 Hinson 13.088.080 13.088.080 18.429.072 Black Hills Capacity Black Hills St~121 181 121.181 180 Glenbrook 978851 Springfield 831 858,137 980 810 ESI-Kaloer 487.840 13.487,840 467 840 PNGC 832 703.105 788317 Cheyeme Sals 24.550 928 24.550,928 515437 Doseret ~emenlal 433.427Ok-701 382 701.382 718753 UMPA II Sole 329098 329.098 810895 Plolno ElecmcG&T 980734 980,734 792 753 Springfield II 464.858 535.184 819.971 CowIilz-llHP 888231 888.231 073,857 Clark-fW 201 372 214,404 884.434 Clark-5EHA 146.292 195812 898.500 Clark-wT 217818 217818 217 810 HU'I1C318 Sales 140 112 140,112 125,092 APPA-AEPCO 067 128 709,098 997 306 APPA-ED#2 875.074 875.074 897 862 APPA-Mesa 317.790 317.790 831.883 Clllzons Power 991,384 'l27 747 975.872 Green MolrtaIns 900 512 350.788 074531 Aathead Sole BPA Wind Sale 400575 Short Tenn Firm P 211.637,558 145.564,090 147.572.095 ShortTenn Firm Intertie 135.099.797 128.384 237 128.280.412 ShortTenn Firm U 273,313.843 218 547 014 'l21,O90,860 Seconday Sales 15.334.072 018558 38,190,548 Neveda 518558 851.878 527 637 FOIl" Comers 089902 107.451 094 730 Northwest 745812 O57 'l27 988 999 SWlntertie 598.962 TOTAL SPECIAL SALES 157,227 015 995.230 017 991 508,0'l2 PURCHASED POWER & NET INTERCHANGE BPA PeoIdng P\Rhasa 920 000 73.920,000 920000 BPA Entillement Cepacity 636 59.852 38,210 BPA ~emenlal Capacity 636 59.852 38.210 Black Hills Capacity 023580 023,580 958,507 CoGenIJomes River 957141 957141 706.636 Mid CoIllnbia 381,444 210.337 210.337 CSPE 728 CoIockun GranU:""ty 086000 086,000 086.000 PGE Cove 245449 245.449 219 230 IPC Re1lm USeR Greenoprings 740420 740,420 923,188 F. ConIracIo - PP&L 51.291.713 51.058.971 52.189.023 WWP P\Rhasa 1989 750 TriSlaie Pl6chass 808 114 808 114 10,4n.744 South IdoI1o Utah to Goshen Area South IdoI1o BPA 10 Paciftc South IdoI1o St~(1.420092)420.092)(489.382) South IdoI1o Re1lm of Storage APS P\Rhasa 134.230 134,230 85.258 Tri Slale Exchange (3O.'l28)(3O,'l28)197.887 SCE FUohase 417.741 417.741 753940 BPA Ex"'1VIgO WWP P\rchase 1994 829,701 829,701 882.080 WWP Exchange 18.500 500 Gem Slale 2n.788 788 2n,788 GSLM 712.217 712.217 873,458 Power Planring 0212012002 12:32 PM Page 1 Attach liP A DR 1.14."s - Normalized 1998 QF Contracts - UP&l 23,654.645 23,654,645 518364 IPP Purchase 27,762 553 27,762,553 27,084.168 Black Hille &.plus 687,830 687.830 473,148BPAGI-707,475 Redding 651.310 700,429 143.775 CoGenIHermieton 731 509 157449 67.482.495 Deseret ArnIe!28,769,579 419 038 051 211 Deseret Monthly Deseret ExpansIon 656.197 656,197 389219 Deseret NF 15.806870 15,806.870 689,590 HLntcene 586 586 39,248 Clark S&J Pu'cha8e (930470) STF Pu'chases PPL 373160 581 303524 923 308.074565 STF Pu'chases UPL 224148,596 145632.779 147241 944 Secondary Pu'cheseo 84,057,890 303,485 731 031 TOTAL PURCHASED PW & NET INT 1 037.148,999 880,200.917 868,181,092 WHEEUNG & U. OF F. EXPENSE BPAlnter1le 423 372 521 449 538 148 Other 944.884 72,963.480 399 070 TOTAL WHEEUNG & U. OF F. EXPE 388,238 484,909 937 216 TIiERMAL FUEL BURN EXPENSE Cenlralla 580096 798 400 63,373 058 Dave Johnston 294098 294,098 294 098 Jim Bridger 610871 90,547 434 92.158 087 Wyodak 18,584,347 584 347 18,584 347 CoIob1p 220,293 021.863 021 863 Carbon 537.570 537,570 537570 Noughton 55,252,041 044,623 58.780233 H..,tinglon 43,233,147 43,233,147 44,739808 H""'"71,594788 71,594.788 260859 BILO1deII 724,844 724,844 724 844 ChoIla 34.718.968 253.727 656 613 Craig 12,807,201 12,808,253 12.809 828Hay-030,081 042,111 085 284 503,908 537,413 922,305 Hermloton 953,484 541,631 20,743 551 Axed Coot 728.077 14,009,201 14.088.909 TOTAL FUEL BURN EXPENSE 493 371 412 491 571 448 500,981 035 -------------------------------------------------------------- NET POWER COST 447 859632 450 027 257 453.571.321 -------------------------------------------------------------- Not POW8l' CostlNot System Load Motgod SysIBm PDIMac SIudy SemI Amusl Study Net Power Cost Energy Analysis POltod 8t1ded 12/31198 (MNH) Power Planning 0212012002 12:32 PM Page 2 Attach IIPA DR 1.14.xlo - Normalized 1998 Type I Type II Type 111 12/98 12/98 12/99 NET SYSTEM LOAD 52,042,337 52,042,337 52,042,337 SPECIAL SALES FOR RESALE Blade Hills 468585 468 585 328501 So Cal Edson (P)608,679 608.679 473040 So Cal Edson (U)608,679 608,679 473040 SMUD 411,747 411,747 370 848 SIerra Pacific 583434 583,434 589,559 IPP Sale 539 798 539.798 473.470 Puget Power II 050 965 050,965 051,200 SIerra PacIfic II 460,679 460.879 459 901 UMPA Sale 48,290 48.290 43.800Ne_(base)438,280 438.280 181 150Ne- (Peaking)179257 APS Sale APPASaie CDWR Sale 613014 613,014 624.198 WAPA Sale 809442 809 442 377,120 WAPA II Sale 580,317 580,317 558,450 PSCo Sale 143007 143.007 158320 EWEB Sale 95 338,380 338.380 324 120 Reddng Sale 370482 370,482 372.301 Clark Sale 369261 369 261 883.888 Hinson 568.980 5&8,980 801 264 Blade Hills Capacity Blade Hills Slolage 921 921 Gleraook 037 Springfiald 239 095 239095 216,288 ESI-Kalser 676 000 676,000 876,000 PNGC 279 269,220 207 579 Cheyeme Sale 930 861 930,861 669.947 Deseret &.wIemenlai 196,093 Okanogan 449 48.449 487 UMPAIiSaie 586 12.588 83,850 Plelns Electrtc G& T 469 888 469.688 306.078 Springfield II 143 800 143,800 145767 CowIIIz-BHP 48,855 48,855 320 Clark-PN 75.880 75.880 105 120 ClarkoSEHA 213.691 213,691 328750 Clark 73,352 352 221 H..ncane Sale 004 004 465 APPA-AEPCO 115087 115087 62.438 APPA-EDt12 683 13,683 194 APPA-Mesa 25,317 25,317 408 CItizens Power 103,682 48,522 '188 980 Green MowItsins 697 345 192,234 Aalhead Sale BPA WInd Sale 35.647 Short Term Ann P 919 597,705 597 705 Short Term Ann Intertie 633.476 803.420 803,420 Short Term Ann U 10,655.705 153.804 153 804 Secondary Sales 520.791 303 262 470 804 Nev-159 379 108 914 253278 F.... ComenI 292,104 174 78,404 Northwest 469 916 698994 SWlntertie 404.400 Secondary Losses 188 258 37.528 TOTAL SPECIAL SALES 361,322 36,415468 36.351.634 --------------------------------------------------------------- TOTAL REQUIREMENTS 403689 457,803 68,393,971 -------------------- -------------------------- --------- PURCHASED POWER & NET INTERCHANGE BPA &.wIemenlai Capacity 675 875 Bleck Hills Capacity 330 330 830 CoGenIJames River 3&4,588 364.588 409 967 Md CoIlll'illa 231.182 230,259 229,210 CInIdIan Entitiement (44 232)(45396)(22.338) CSPE 168 397 179.473 112,435 CoIodnm (169 816)(169,616)(183 106) GranL Co\riy 800 87.800 87.800 PGE Cove 24,000 24.000 24.000 IPC Rehm (80,261)(80,261)(97.855) USBR Greensprings 52.880 52,880 919 F. Contracts - PP&L 551.726 551,726 551,726 WWP PIRhasa 1989 TriState PLRhase 292.335 292,335 264,701 South Idaho Utah 10 Goshen Area (307.262)(307 262)(295,217) South Idaho BPA to Pacific 307.162 307,162 488.733 South Idaho Slolage 79.720 79,720 61.171 South Idaho Rel1m of Storage (147 508)(147 508)(57927) APS PIRhasa 11,300 11,300 903 Tri State Exchange 748)(2.748)17.989 SCE PLRhase BPA Exchange (1) WWP PIRhasa 1994 61.800 81,800 62.800 WWP Exchange 500 500 Power Planring 0212012002 12:32 PM Page 3 Attach IIPA DR 1,14.lCIs - Nonnalized 1998 Gem Stale 65,015 65.015 64.519 GSLM 34.917 917 43.632 OF Contracts - UP&L 495.222 495.222 495.222 IPP P\Rhase 539,798 539,798 473.470 Black Hills P\Rhase 164.572 164,572 267 000 BPA Glenbroolc 146.350 Reeking P\Rhase 136,715 136 715 152.700 CoGenIHermiston 701.988 981,922 681.922 DeserelArnlai 643.977 968.803 182,954 Deseret Monthly Deseret ExpansIon 226.929 226,929 220183 Deseret N F Pll'chase 478,085 478.085 357,183 APS Exclw1ge (78.752)895 (93.072) HLllicane P\Rhase 863 863 226 Cln S&I P\Rhase 11.037 Foote Creek 910 124.725 124 725 STF PIRhases PPL 17,117 375 512,782 14,512 782 STF PIRhases UPL 700.509 790.429 790,429 Sec:onda'y PIRhas..941 543 340 100 893 341 TOTAL PURCHASED F'W & NET INT 36,847,424 058 132 32,941,268 COAL ARED GENERATION Centralia 164,387 996 845 042 172 Dave Johnston 838.795 838.795 838795 Jim Bridger 955 180 947 813 141,437 Wyodak 180335 180 335 180335 CoIslrlp 018027 018.027 018027 Carbon 359,236 359.236 359,236 Naoq,ton 515.243 583611 848,492 HLI'IIington 383.050 363.050 585,315 HLI'Itar 859,475 859475 371.703 BILI'IdeII 164,371 164371 164.371 Chalta 382,623 329617 372,348 CraIg 320.171 320.045 320.520 Hayden 559.442 560 994 585.949 306,282 307.649 282.541 Hemiston 681,001 681 001 681,001 Trojan TOTAL COAL ARED GENERATION 49,865,600 508 866 570.244 SYSTEM HYDRO System Hym-o 890281 891.540 892,331 Draft From 354 (535)(9,870) TOTAL SYSTEM HYDRO 690,835 891,005 682461 ----------- ----------- ------------------ ----------- ---------- TOTAL RESOURCES 403 659 88,457803 393,971 ----------- ------------------------------- -------------------- Power Planning 0212012002 12:32 PM Page4 Attac:h IIPA DR 1.14. ". - Normalized 1998 MarrIed 5rs"""AcIuaI AcluaI12 mon/hs ""'*'9 12131198 Net P- Cost AnoIysio (I) Total JIII1 Fob Mil"I'fJf May J..,Jaj Aug Sop Oct Na.I SPECIAl SALES FOR RESAlE Black HIs 474 275 1.495,674 406 520 439 767 458 311 384310 346516 424607 586,993 488289 497 722 460,194 So CaI Edson 163,320 197,033 309,306 104,511 731 460 501 869 417,520 185,938 385946 217 128 235,488 248673 SMUD 028,040 573 692 195,999 452,675 577,197 120532 100,965 365,645 440 099,433 793,845 867859 Sierra PaOIic 789 661 553 940 405 063 525906 591,976 013833 406,532 559 105 653519 554,043 511.971 464 ,172 IPI' layoff 762 553 362,608 360 527 303241 304409 232699 375204 160600 447 158 311 431 298178 313,058 Puget Power II 067385 108 356 804,588 512448 512554 419837 435 131 793849 179 264 039 096 139086 941,578 Sierra Pacific II 410622 130,745 950,287 126305 213445 973968 049 982 308,176 200,187 130 065 064844 102,373 l.t.IPASaie 794706 229,515 220,549 230,166 230,683 229515 226,481 231,176 243,263 236 209 242,105 235,497 Nevada (Base)618,075 352,976 284,530 352,976 334 126 865 611 332,693 352,976 352,976 345 300 341 802 334 503 NeYada (Peamg)105,853 158)158 920 217 119 788 386.111 368,390 312,845 (1,498) AP5 Sale 689,548 689,548 N'PA Sale 975385 975,385 CDWR Sale 243 799 412,976 507410 446 783 733 173 380 135 409 640 618 462 612,416 471,580 548,412 479408 WfIl'A 731 180 309784 544 004 625 043 848 191 442 804 445434 5691155 559679 664437 714 104 666.058 WfIl'AIi 927.504 662,036 924 014 111 348 869096 783 731 026368 041 392 064 304 135 282 166 730 112,005 PSCO 169 289 963,006 920 375 944,106 020435 843480 983533 071,231 002,418 746 367 075 368 872,056 EWE!! 95 521,675 587,155 576 370 586,166 726,378 581 713 573,797 700,651 890,692 865 265 915,338 851450 Redding Sale 12,532,217 094,456 006 574 047 640 039,050 054 185 937,719 095 743 236 336 115 379 917,549 980593 0erX Sale 383,979 088 814 660 819 380384 142,574 062,835 584,707 694 114 089 656 717,504 696,891 228 317 Iinsa1 096,080 181 504 174656 284992 262,332 300512 260 170 300512 300 512 256,950 753,940 Black HIs COpedly Black HIs Siorage 121181 422 (27456)(27,456)(24 298)820 175 (16 500)710 689G-..ok 978851 (610 798)916 757 448 783 224 099 SpmgIieId 517631 509,099 467,191 485 240 553 876 875 000 467,069 551 298 439 370 528,037 702,221 ESI-Kaiser 487640 143,416 043.406 143,416 108 691 143 416 110 080 143.416 143,416 110080 144,805 110,090 PNGC 832,179 419 002 300 207 417,892 510 944 634,636 579268 672,317 616 180 01eyenne Sale 550,928 145 516 001,511 075 663 940 690 959 853 900,497 127,106 084,043 035,445 037,171 028719 Deseret Supplemental 433.427 894 130 370 193 084 261,930 220 155,000 180,000 474,356 150673 Okanogan 701 392 141 69,007 789 951 703 30.442 937 198 622 61,880 581 lMPA II Sole 328,099 19,302 107,906 119,280 17,840 474 296 PIai1s 8ecIric G&T 960,734 162375 745 514 927,599 655,939 619 236 833,606 142,680 747389 008,474 751 424 233836 SpmgIieId II 484,656 354240 314 880 341 120 172,120 174,400 395 496 351 552 CowIitz-B1f'999,231 287 518 969 75,991 71,959 691 926 059 048 321 911 OerX-201 372 100375 097 697 913 96,076 535 652 107060 102 961 865 103 878 OerX-SEHA 148,282 275540 257 889 281 580 268,949 281 576 260860 240955 263 387 257 436 246875 260 970 OerX-217,616 100 086 070 090 108,462 110,457 120281 120464 117,502 116901 118,289 IUricane Soles 140,112 604 044 388 472 444 444 892 620 14,084 208 176 N'PA-AEPCQ 067,126 500 965 155,496 512 858 612 458 285,348 N'PA,ED#2 875074 222,979 202524 233545 216126 N'PA-Mesa 311790 253,097 256,674 274 580 256144 ID,235 Citizens PCMOI'991,384 372,092 350 938 395 842 405 469 352 236,652 431 746 392 486 Green MCI.II1Bins 900,512 797 790 87,230 285573 208,606 112455 (26987) Aalhead Sale 321,109 144302 SPA Wild Sale SherI T onn Rrm 620,250,997 245359 402 659 210,854 33,398,109 34,543 537 388,920 50,540,008 026334 94,361,441 492 141 675408 SeaJndary Sales 88,341,109 261,886 809 304 864 763 11,414 461 328,171 276,366 913,696 664,921 842,483 583,025 455913 ------ ------- ---------,- ---- --- ------ --- TOTAL SPECIAL SALES 234,555,155 100487579 631,719 043954 85.224479 477428 100.335.226 98.544,309 133440 543 144 128 458 95.283.553 93,709 975 PURCHASED POWER & NET II'ITERCHANGE SPA Peak Pu"d1ese 73,920,000 160 000 160000 160000 160,000 160,000 160,000 160 000 160000 160000 160000 160 000 Pacific Peaki'1g CorI~ecb 147,232 645 286 88,849 499 569 88,685 90,067 134057 90,522 112,197 110,715 GaGen/James River 15,857,141 530 112 347372 476,483 388,320 218,557 209,321 238,516 329.426 186736 161,931 404 973 Mid CoUnbia 361 444 296,660 265608 285,185 428,199 578 934 270,399 407,165 180087 932,084 154.917 391,466 CSPE 728 33,893 33,893 893 (100,951) GrenI Cao1ty 066000 223,790 174,650 203 630 259315 326 970 349,860 359 730 334565 248 360 206,500 165480 PGE COve 245449 461 974 465 961 961 961 961 961 961 961 961 USSR-Firm 740,420 718 284 584 67,584 (67,584)19,336 97,928 601 948 961 731 F. CorI~ec13 - PI'&L 51,281,713 562346 801 125 367.454 139,192 323,785 748 336 192380 000553 049 714 522 723 018229 WWP Pu"d1ese 1989 750 750 TriStete Pu"d1ese 808,114 858 185 874 165 906,286 889,793 931 554 814,606 953,979 953,780 907 270 928,924081 South Idaho Storage (1.420,091)(118341)(118 341)(119 341)(118,341)(119 341)(119.341)(118,341)(119,341)(118 341)(119,341)(118,341) APS SUpplemental 134 230 553 445 36.232 TriStete Exd1ange (30 229)255,915 251 570 271 766 (285,705)(272800)(264,550)(274450)(217 750)(262 900)248,952 271.028 SCE 1'u"d1ase 417 741 491,220 481,220 604551 170 150 540 300 SPA Exd1ange WWP 1'u"d1ase 1994 629,701 442,781 900 559 648 163 712598 (74400) WWP Exd1enge 500 (84 700)(152 350)54,450 186450 57,750 Gam Slate 217,798 190,500 190,600 204,000 190 600 195 500 190 600 190.600 190600 214600 128,788 196600 GSLM 712,217 104,699 765 972 790 110 063 20,497 62,392 139,414 QF CorIIrecb - IP&L 23,654,645 864 824 011551 449 035 769 971 660 885 405,106 090,097 158,180 088322 968,865 319,498 IPI' Leyoff 762,553 362 608 360,527 303 241 304 408 232 699 375 204 160,600 447,158 311431 208,779 313,058 Black HIs l'u"chese 96 667830 330000 163,093 325 114 360000 375 090 200,000 13,215 311 626 263 878 253,968 30,340 SPA G_ook 707475 665075 688200 666,000 688,200 Redding I'u"d1ase 651 310 305029 180 752 242,618 236652 216,428 246,501 192,896 194,413 225 593 243,622 186,356GaG_ton 731509 061,637 805,607 423,906 5,755,151 934763 208,730 649,405 980 813 826 866 693,279 130,596 Deserel AmuaI 28,769579 475 912 239 146 358,417 330023 402,504 2.419,150 380,854 499 799 401 599 441 609 348726 Deseret M",,1I1Iy Pu"d1ese Deseret Exp- 656,197 809 149 340 150,000 (111 791)428,376 31,717 171 196 210,000 170000 115,198 120,599 Deseret Non-Firm Pu"d1ese 806 970 706 816 940 144 941,523 71,476 421 041 666,509 529,639 400 201 798,401 542888 601,983 IUricane 1'u"d1ase 27,586 4,731 282 830 100 494 1.110 280 927 999 536 422 0erX S&I Pu"d1ese (930470)121872)191,402 SherI T onn Firm l'u"d1ases 597307 177 849 326 25,024,122 556382 975 879 218546 447 155 554 739 108646 83,662,270 826 720 173 886 SeaJndary I'u"d1eses 130 227 072 10,661,116 11,721,857 12,773956 265 799 569453 486,976 789,264 12,868 613 10,313,051 981277 289 625 --- _..--,----------, --__m_m_m'- --__mm__- --___--'--m__- --,---_0.-.. -- --------- -------- ------- ----- _0.0._,0.- TOTAL PURCHASED PW & NE 083,316,192 494.212 192 162 199 868 842,057 632 886 194,219 109411,565 136 013,528 131,379 057 594 923 77 ,954,857 TOTAL WHEBJNG & U. OF F.74.244,409 633 096 852,546 369,658 017,551 098 121 5.243458 027,232 971 921 056,827 163,6.541,144 THERMAL FUB. BURN EXPeISE Centralie 198652 797 219 060878 048 753 6,498 692 907 787 072 197 168 319 749829 951 306 821,049 044 988 Dove Jch1slon 000548 951,119 531 855 854405 924 922 752 991 510 585 656 312 656312 114463 780 975 386631 Jin Bridger 102 316425 471,545 982,260 109 049 393 322 117 195 995 542 187 192 124631 5&4,590 991,121 290198 Wyodak 306918 588,854 565545 659 016 842,931 596,975 678 580 607 577 765897 660,534 666 809 447339 Cdsq,996621 693.421 613,638 632 946 643 141 759 645 910 295 896106 776 140 750,158 481 632 286850 cnon 947752 687 885 792,503 832,023 847 619 798 855 749 508 779902 750 057 770,449 766617 676449 Naught""62,196,454 907.691 539,976 5,799 078 546 456 484,740 655 942 180,261 088.879 443 648 988262 639 152 HLnlinglon 49,601 639 160 299 486 403 747,605 609 608 983098 671,809 735,457 112,714 715 768 298,174 579508 HLnter 72,650,282 931 751 989 150 930.921 506 285,511 540,675 930,868 277,808 031 044 825,834 10,776,379 607,452 310 676 304 666 315027 312,685 280,259 294,555 281.263 258,928 301 318 313 702 306,723ado26,918,093 008 255 075 424 459091 485,702 246437 259 578 936,551 748 713 872,408 205,315 268,858 Craig 153,494 149 246 014,490 741 224 582 772 1.039562 037 881 147,099 172 419 014484 109,026 119,836 Hayden 833 152 603 909 450 256 606583 579343 430,050 498,406 603,802 586 214 624911 260,379 255,371 Gadsby 559 223 119 146 119 119 120 153,843 980,219 206 635 896317 900,090 734.447 HemlistDl'l 537 333 157 563 991 912 727692 195284 720,546 668,671 907,392 164 741 133528 142,011 359,048--______mmm. ------_0.,..,-------- m.., ------..--, .. h_m----m_- ____n--m-----_m____m_- --_m_--____h ------------ , ---------- .m_' --_-- --------- --------, TOTAL FUa BURN EXP~E 521 924949 318 649 42,390 102 4&4413 40,941 001 32,474 771 32,698 948 008,321 49,438,917 844 926 47,648,595 57,191,666_n_n_nn_n- --_u-------- _ _-- n____- ___-- nun nn_uun _n_nun-nunun_-nnnun_-_nu_nnn n___ ------ h___nnn-_____n_n__nnnnnn- --_h--_----- ------ ----- un_on _n__-_nn n__n_nn-nn_nnh-_nn_nn_-_n__ ----_- nnnn_n-__--__nn-- Power PIInWIg 02/2012002 pogo 1 Attec:hIlPADRI.14.Jds NET POWER COST 444,829,484 958,31.603 O91 31.919,185 536 139 728360 801 291 "_, 809 51,993,823 152,352 42.113 692 917 692 --------------- ------------- ---------------------- __--___n ----------------------___ _--_hn- --------------------------------------------------------------- ------------- ---------------------------------------------------------__ ____n__- ---------------------------------------------- Her pa;ver CDs_' ~1Bm 911 911 10.12.25 10.11. AIetged S)slom -... AcIJJa/ 12 moolhs erDIg 12/31/98 Not P- COst EneIgy Analysis (MWH) Total Jan Fob Mil'May J...JLi Aug Sap Oct Nov NET SYSTEM LOI\O 080,566 438,205 050 098 4,225,318 042 129 383 314 011 028 812161 133,303 4,216095 145 391 4.221,240 SPECIAL SALES FOR RESALE Hils 466 585 38,251 919 695 215 510 30,105 011 232 44,535 449 613So Gal Edisoo 211 350 109 615 146 104,988 959 459 ooo 109113 119 240 112,501 114 155 114 105 SMUD 411 141 041 11,626 865 255 150 992 100 400 124.002 519 509 Sierra Pacilic 583,434 421 39,455 548 51,962 654 293 52,204 211 865 138 022 IPI' Layoff 539 198 081 619 896 40,490 120 131 32,750 55,319 639 320 142 Pllgel Power II 050965 104,220 990 400 70,406 144 012 803 104910 200 102100 836 Sierra Pacilic II 460619 141 015 892 792 213 34,609 098 038 103 443 549 UMPA Sale 290 140 696 124 141 095 960 118 259 942 201 910 Nevada (Base)438 280 31,200 600 37,200 658 445 35,495 200 200 691 109 35,975Nevada (Peaking)119 251 200 205 140 45,802 (90) APS foPPA CDWR 613 014 384 800 150 750 880 44,352 54,780 400 068 200 800WN'A 809 442 51,443 390 536 73,081 921 095 68,013 370 053 212 14,162 WN'AII 560 317 29,800 31.425 551 39,825 280 48,200 000 220 000 614 211 PSCO 143 001 96,180 121 963 791 254 91,460 103014 65&440 528 400 EW8I95 338 380 22,595 050 22,545 630 22,320 21,920 330 400 35,145 37,625 34,465-0 Sale 370 462 33,253 28,085 30,810 240 31,243 29,716 002 414 35,305 26,159 26,351 Clark Sale 369,261 241 280 152,880 145,080 148098 65,996 165 322 333 113 135 125 128 &89 ......, 568,960 648 56,304 884 56,544 190 544 56,544 650 32,180 Power PIan'ing OmO/2002 page 2 AIIad1I1PA DR 1.14.'" - - Capacity - - Storage 921 402 496)(2,496)208)620 525 500)610 699037(26,556)859 991 743 Spmglield 239,095 20,760 555 505 26,085 725 600 935 380 530 760 28,545ESI.I(aiser 876000 400 200 400 71,900 400 000 400 400 72,000 500 000PNGC279,277 23,586 862 415 29,564 200 600 650 000 Q1eyeme Sale 930,861 82,588 380 80,113 245 653 958 80,090 875 304 237 620 Doserol SUpplemental 196093 881 755 351 846 400 000 004 160 Okanogan 449 506 570 092 308 232 016 572 125 816 098 608l.t.1PA II Sale 12,586 864 117 460 880 1938edric G&T 489 668 463 880 115 655 41,193 785 33,101 283 535 533 117 Spmglieldll 143,600 21,600 200 20,800 10,400 000 600 200Cowi1z-B1f'855 3.470 303 966 217 970 282 469 138 579 200 466Oark-75,860 396 906 150 929 124 007 262 857 548 975 4600ark-sEHA 213,891 18,918 17,594 19,361 18,441 361 860 307 966 17,570 380 306 Oark-352 223 195 275 952 585 720 385 396 196 155 249IUrica1e Sale 004 239 427 371 374 373 373 639 665 503 436 292APPA,AEPCO 115087 106 875 28,863 36,203 040APPA-8.J#2 663 672 2.403 337 251 APPA-Mesa 25,317 420 599 760 566 972Otizons P""",103,682 893 160 709 080 200 200 960 600Green MlU1tam 24,897 623 125 988 203 928 766 526Flathead Sale 155619 564BPA Wnd Sale Short Term Ffln 667098 037375 933482 482 310 779842 899 878 742,201 884 760 326,653 789 036 917,005 1.796,075Secondafy Sales 368 103 797586 660033 540 961 521,657 494 802 462713 156 111 203 210 175 534 61,604 106,953 ------------- ---- ------ --- -- -------- TOTAl SPECIAl SAlES 45.364.243 4,203920 756331 387,016 3,557,554 405 587 4,255,918 3.248.208 859 309 338 532 348 919 3.234,443----__n_n_n- -_---nn_n- h______--- nn__n__- ----------- -______h_-______n___- ------------__--____ ___-n____---_n___ --_-- _nn_____-----____nn_- -----n__nn -----_-n_- __n______-n______---n_--____--_____n____-___n____---_n___ ___------------------------ _nnn____- TOTAl REQUIREMENTS 424,809 640 125 806429 612.335 588 683 768 801 326 946 120368 582 611 8.554,627 494.316 455683____n___--__-- ___n______-- ____n____- ---------------------- h---_n_-__hn____n _n__n____- -------- n_n______-_nn______- ------------ ____n__hn__- -______n___- -____nnn ------------------------------- __h______--n___nn__- ------------ n_n__n__-_n_____-n- ------------ PURCHASED POWER & NET INTERCHANGE Pecific Peab1g CalIracIs 205 (42)962 600 489)477 1.416 092 341 067 (543) CoGenJames River 364 566 958 783 733 31,947 840 27,629 296 30,373 113 544 32,099Mid CoUnbia 151 158 208 177 224 830 207291 116 004 218,059 238,460 180 906 166,503 137478 124,217 142,026Canadian EnbUemen!(44 232)456)156)573)708)841)718)842)842)718)862)697)CSPE 188397 345 473 443 13,888 410 13,908 908 16,908 908 14,390 13,908Cckx:Iam (188,616)(25 077)(12676)(22.430)(16546)(11)149 174 (21 375)(24 408)(25144)(25537)Gr...1 County 600 394 990 818 408 342 996 10,278 559 096 900 728PGE Colle 24,000 028 884 028 978 028 980 028 028 880 030 980IPC ReI1m (80,261)353)871)851)734)(7,118)(10541)(8,363)308)385)059)014) USBR 52,680 010 538 855 483 574 220 374 084 118F. Caltrocts - Pl'Al 551,726 850 881 028 56,881 443 377 262 42,936 5&4 591 44,258WWP_se 1989 TriStale l'In:hase 292,335 288 947 726 23,653 867 18,765 27,827 27,814 24,790 26,162 25,883South Idaho (67 888)966)(28 516)(24651)304)541 20,661 593 437 751 495 (22456)APS SUpplemental 11,300 750 450 100TriSta'" Exchange (2,748)23,265 870 706 (24 155)(24 800)(24 050)(24 950)(25250)(23,000)22,632 24,639SCE Pll"chase BPA Exchange (50,000)470 125,544 209 (30 240)(31280)(30 670) WWP Purchase 1994 600 625 895 46,050 230 200) WWP Exchange 500 700)(13850)950 16,950 250 Gem State 015 646 16,169 15,722 268 12,210GSlM917759353726945147331 836 337QF Caltrocts - !PAl 495,222 46,420 38,570 021 646 756 417 393 007 539 882 458IPP Loyoff 539,798 49,081 48,619 39,896 490 720 137 32,750 319 839 320 142_-_"096 164,572 970 700 26,735 28,000 220 362 325 11,225 100 235 150BPAG_ook 146,350 35,950 200 36,000 200 Redcq P\I"chese 136 715 093 944 005 710 709 12,047 417 12,776 013 11,803 098CoGenlHenniston701988170129155,044 136224 157 722 42,475 985 146418 167,932 162,865 153463 168 640Deserel AmueI PLrchase 643 977 141481 127,951 134,770 133 144 137 286 138 237 136 055 142,846 137,234 139521 134 213Deseret Monthly Pll"chase Deseret Expension Pll"chase 226,928 20,247 18,025 20,510 545 16,793 076 19,166 19,316 905 16,225 19,653Oesero! Non-Ffln Pun:hese 478,085 365 628 066 55,579 869 55,852 297 22,154 954 298 391APS Exd1ange (76,752)950 203 (28 350)(59,940)(78 870)(76 375)(39925)13,680 550-PII"cI1ase 663 148 411 125Oark S&I Pll"chase 11,037 (2,939)976Short Term Ffln Pll"cI1ases 817884 950012 1.436 537 347 015 412,625 779221 165,573 333 975 500654 778,961 698 985 408 236Secondary Pll"chases 667627 504203 731,725 695 184 953437 342,724 352,686 408 283 449699 352,990 233 741 391 618 ------- ------ -- --- -- ,----- --- --- ---,-- ---- TOTAl PURCHASED PH & NET 483,574 3,355,380 817 456 757 125 017479 842.556 385081 482.208 885858 763,284 580 673 2,505,385 COAL ARED GENERATION CenIraia 512501 411 230 350,395 385 242 432 728 185 007 130181 422045 458 911 442,310 463 197 394 190Da... Johns!on 928,660 558,742 481 912 500 383 545.448 520 160 450049 470 166 483 019 447,505 486 604 466,398Jill Bridger 10.753560 976 166 887,023 934,565 906 615 680 040 845839 924832 917 668 902,377 929 654 968,732 WyOOM 288 651 188681 183286 192 281 190 838 181 100 191202 191442 200,430 192,994 199191 197829Cds~145 951 545 90,392 103130 670 253 618 103609 92,553 642 135 90,902Carbon288602106082115,383 121 463 376 110 433 107307 112 706 111,702 110,524 107237 93,094 NaiqlIon 223,025 467341 436,981 474890 416 723 436 724 367301 458877 463 800 393,219 400643 455 244 Itm1gIon 452,895 604 225 521,894 379721 357 233 538 522 521552 621 961 558 901 581 934 610750 571,151 552,503 693 751 688517 746807 648 078 358 686 382673 457 123 700 329 598,576 686788 689 113160,057 828 14,939 655 094 13,630 12,477 500 610 550 424 554CIda363,942 215,760 207,380 173753 174 882 139 172 152,136 188 284 222,139 215 801 221258 222 196 craig 268 721 121 284 102 991 177 410 105,942 106 789 118 568 105582 115,134 120646 114 450 Hayden 531 038 410 42,928 514 372 43,447 895 961 574 41,152 565 23,704Gadsby349,380 (444)(370)(391)(303)(342)900 188 93,960 85,478 35.642 694Hennislon701,978 170 128 155 044 136,223 157,494 703 66,949 146 341 167,926 162 846 153 680 168,640 Trojan (487)(55)(40)(41)(39)(37)(34)(36)(35)(35)(38)(42)_----'--_m.__m__- -----,----- ,------ ----- ---- --- --- ---- ----- --,-- -,--- ----- TOTAl COAl FIRED GENERATI 521 917 683874 4,288.556 4.300.372 048719 445440 481 733 352.567 638069 4,501 007 547 404 484 849 TOTAL SYSTEM HYDRO 419,258 600971 540417 554 838 473485 480805 450,132 285 593 257 .583 280 326 366,238 455449----___n ------- -- -- ------------------ ---------- ----- ----- --- --- n___- ---- _n____- ---- TOTAl RESOURCES 424 800 640 125 806429 612.335 588 683 768,801 8.326 946 120,368 582,611 8.554,627 484.318 455 683 --- ----__nn_- ------_____n n______- -- ---------- - __n______-nnnn--- --_____n__- ------------ _nn______-__n______--__nn_____- ------------ --_--__nn_- ----_____nn n______- -- - ---__-_n- __n____n-nnn_n_- --___-nnn n___-_--n-nn______--__nn___---nn_nn__- ------------ Power PIarr81g 0212012002 page 3 AItadIUPADR1.14Jds Dee 505. 518.568 860 799 549 801 291 943 191 608 160 235 239,547 1.357,606 623,394 540797 131 198 026,924 666.699 007,073 037465 465 705.396 143,416 622332 214,714 800000 141 332,663 380 848 651 116 263 252,275 114 904 736 313 997 188958 176807 956227 946119 ------ 108,237841 160 000 342 455484 159.840 213,150 961 317 565 884 966 053 (118 341) 288,695 540 300 (45 100) 184,800 626 860321 291 943 41,596 180250 280.756 471 680 125 754 187 269 865 909,507 606.086 ------------ 516 038 410 129 078,744 870 077 14,029,789 427 184 542,650 705,885 922,370 502 594 342 945 317 649 648 238) 026,455 333 948 682,251 368 935 --,--,------------ 503840--hh--__---h___h Power PIarr81g 0212012002 page 4 AtlachIlPADR1.14.Jds 192,065 ----------------------- Dee 684,277 190 129 003 086 595 485 105354 796 092 :J75IJ7 850 66,166 54,125 100208 355 28,814 169200 p"""" PIIn*1g 0212012002 page 5 AIIad1IIPADR1_14Jds (2,235) 715 400 400 83,798 92,871 506 133 20,800 795 246 827 021 312 880 737 055 078481 186939 768,507-_--__--n-- ------------ 452 784_--___n___-______n_n- 316 253 187 207 819) 908 (21 735) 090 028 (5,664) 624 634 28,612 (45,473) 26,245 100) 483 103 46,485 550 12,000 174091 141,239 19,468 632 78,325 005 080 250,337 O5O 437 065 518274 960,049 190 104502 96,295 451 282 585 051 802 064 796 231 081 120,749 29,595 368 174,094 (55) 738 387 663,420 452,784____n___ --------------- Power PlanrWIg 02120/2002 page 6 AItad1I1PA DR 14m PadtICoIp PDIMac SIudy SemI AMusl Study Net Power Cost Analysis Petlod ended 12/31/99 ($) Type I Type II Type III 12/99 12/99 12/00 SPECIAL SALES FOR RESALE Bleck Hills 17,771 134 17,675,045 13,055,291 So CaI Edson (P)194 698 194698 608,842 So Cel Edson (U)194 698 194698 25,608,842 SMUD 331,360 539662 101.625 Sierra Padflc 16,102,184 717,263 654.345 IPP SIIIe 24,849,901 849901 855 8&5 Pugel Power II 48,&92,262 48,202,769 124 &92 Siena PecI1ic II 25.768995 743.357 174 136 UMPASele 840096 8&5 347 195,812 Nevada (base)580,698 Nevada (Peeking)585,582 CDWRSIIIe 34,681,391 30,945.999 749.720 WAPA SIIIe 926,221 225 747 045681 WAPA II SIIIe 25.201 550 25,201,550 24.129438 PSCo SIIIe 043 345 48,610.500 020 114 EWEB Sele95 082,767 240267 154844 Redding SIIIe 901,358 352721 234,&33 Clerk SIIIe 29.957.973 784359 26.842.692 Hinson 22,010,747 010747 11.792.445 Bleck Hills Capacity 450.000 Bleck Hills SIonIge 35,310 35,310 120,000 Springfield 220.855 398.198 486 ESI-Kaiser 13,487,840 13,487.840 PNGC 952,059 068.057 157 057 Cheyeme SIIIe 25.392.057 25,392 057 368 458 Deseret ~ementaI 999,437 999 437 516704Ok~716,753 716.753 706952 UMPA II Sale 082,&38 082 &38 133245 Plelns ElectrlcG&T 942.760 942,760 827,075 Springfield II 616,768 668.848 748670 CowIltz-BHP 154 273 154273 073657 Clerk-FW 323,226 323228 980 113 Clerk-SEHA 573,001 Clerk-wT 416,212 416.212 367.028 HllTicene SIIIes 191.100 191,100 208,487 APPA-AEPCO 981.679 981 679 687,769 APPA-ED#2 714,683 748 895 940,200 APPA-Mese 367511 486 038 704,603 Clltzens Power 857.824 857 824 083.860 Go-. MoI61tains 698,936 594,535 479,761 AeIheacI SIIIe 12,260,608 14.684,688 14.684.889 BPA WInd SIIIe 776.167 577.551 617,276 Short Term Ann P 150107,168 169 530 207 163.354,314 Short Term Ann Intertle 102360 006 115 097 763 123,765.993 Short Term Ann U 236921 840 266 859115 284 158.727 Sec:oOOsy SIIIes 36.090,217 44,257683 85,352,311 Nevada 058.851 445.439 F.... Comers 71,373 16.859 732.144 Northwest 22,151.172 002,728 46,634,870 SWlntertle 809,021 236,496 11.239,858 TOTAL SPECIAL SALES 028 936062 078843 634 099 817,172 PURCHASED POWER & NET INTERCHANGE BPA Peaking PI.rchese 73.920,000 73,920,000 68.040.000 BPA Entitiemenl Cepedty 36.081 28,224 26.754 BPA ~ementaI Capacity 36,081 224 29.754 Bleck Hills Capacity 629,134 629,134 204.899 CoGenIJemes River 16.251.441 251 441 16.910,922 Md CoI.m.ie 16.221.401 18.851.030 16,851.030 CSPE GranLCouIty 086,000 066,000 086.000 PGE Cove 224.688 224,686 232,758 USeR ~ngo 048025 048.025 722 521 Contracts-PP&l 49,210696 160231 168 727 TriState PI.rchese 10,337,695 337895 10,390443 South Idaho Ubtllo Goshen At South Idaho BPA 10 PecI1ic South Idaho Storage (445,770)(445,770)(543.373) South Idaho Rebm 01 SIonIge APS PI.rchese 61.477 61,477 591 Tri Stale Exchange (295515) SCE PI.rchese 304417 153.773 580 034 BPA Exchange Alliota PI.rchese 1994 484 036 484,036 020,552 Alliota Exchange (57750) Gem State 297 095 267,095 297095 GSLM 536,957 536957 673,458 QF Contracts - UP&l 24,553,955 24,553,955 23,541.441 IPP PI.rchese 24,849.901 24.849901 26.8558&5 Bleck Hills &.plus 723.673 223,676 775,251 Redding PI.rchese 2.421.950 269.919 687,506 CoGenIHemislon 187,360 71,845361 71.152 287 Deserel ArnIeI 674,582 22,553,683 18,314 236 Power Plamlng 02/20/2002 12:33 PM AltacllIlPA DR 1.14.)ds -1999 Deoer8t Monthly 386 055 133803 Deoer8t EIcpanoIon 2.023,364 952,177 2.238.754 Deoer8t NF 092,543 284,856 12.005.082 Hlftlcane 28.435 28,435 30,834TI'IIr18AIIa-43,835 555 S"IF PIRhBses PPL 292.878,893 342.166144 370 121 352 S"IF PIRhBses UPL 195,075959 197,690912 210 741,535 Secondary PIRhBses 349,820 &3,333988 82,008,534 TOTAL PURCHASED PW & NET 928,588,428 976,243,900 049,382,018 WHEEUNG & U. OF F. EXPENSE BPAlnlBrtle 112 845 311 555 Other 71.282,488 697 682 069,066 TOTAL WHEEUNG & U. OF F. EX 266,580 70,784,527 71,380,841 THERMAL FUEL BURN EXPENSE CenIraIIa 72,217,929 75,104 958 198 Dave Jomoton 31,200,918 27,703 710 27.784 341 JIm Bridger 709,747 93,882,290 93,916,125 20.169.150 20.672,224 20,729,810 CoIatrip 832,177 031,521 055,451 Carbon 160,83&160,83&184,822 NIIIJ!t1fnn 84,700,505 84,701,731 57,091,506 Hl81IIngion 43,016,971 43,016971 144609 Huller 82,354699 82,354699 384 238 BIInIeII 039505 039 505 050 981 Chona 36,652.988 38,109 030 228 013 Cnig 520.112 13,078 583 116 075Ha~267 521 944 925 963,416 Gadaby 023,042 149.389 149.590_aton 109 312 23.765,334 23,018,745 FIxed Coat 484,131 14,760,893 14.847,481 TOTAL FUEL BURN EXPENSE 506459,521 510.298,577 452,843.690 ---------------------------------------------- NET POWER COST 477380487 480661,070 473789,177 ----------------------- HeI- COSIIN.r S,sI8m Loa 9.41 Power Ploming 02I20J2002 12:33 PM Page 2 AIIBch IIPA DR 1.14.x1a -1699 P8cIIICoIp $QmI Amu8I Study PfJltod -- 12/31/99 NET SYSlEM LOAD SPECIAL SALES FOR RESALE Bladt Hills So Col Edson (P) So Col Edson (U) SMUD SI",",PacI1Ic IPP Sale PugeI Power II SI",",Pacffic II UMPASaie Nevada (base) Nevada (Peaking) CDWRSale WAPASaie WAPAIiSaie PSCo Sole EWEB Sale 95 Redclng Sale Clerk Sale Hinson Bladt Hills Cepadty Bladt Hills Storage Sprtngfteld ESI-Kaiser PNGC Cheyeme Sale o..-et SI.WIemenlal UMPAII Sale PloinsElectricG&T SpringfteId II CowIltz-BHP Clerk-FW ClerkoSEHA Clerk Hlnicene Sale APPA-AEPCO APPA-ED#2 APPA-Mesa Citizens Power Green Mow1la1ns Aelhead Sale BPA WInd Sale Short Term Ann P Short Term Ann Intertie Short Term Ann U Secondery Sales Nevada FOIl' Comers Northwest SWlntsrtie Secondery Losses TOTAL SPECIAL SALES TOTAL REQUIREMENTS PDlMac Study Net Power Cost Energy Anelyois (MWH) Type I Type II Type 111 12/99 12/99 12/00 51.078814 51,078 814 51,078,814 538,942 538,942 338 185 811,243 611.243 483,120 611 243 611,243 483,120 551,723 350402 350,402 589,046 589046 209,309 550716 550716 543 636 046,435 046435 054 080 480,314 480,314 461 161 43,827 43,827 35,040 181 150 440 608416 608418 613.200 380765 380 765 469,060 630006 630,006 582 301 169,033 169,033 159486 301,615 301,615 189,107 379,626 379 826 341,701 221,380 221,380 109,053 956,989 956,989 512,715 210 189 345 189345 216,960 876,000 676,000 283,375 290,482 226,027 935,045 935,045 966,908 449,526 449526 317,762 47,467 467 46,616 76,548 76,548 43,072 251,046 251,046 149,454 145,600 145,600 146,474 65,186 65,186 61,320 81,849 61,849 59,175 171,386 86,771 771 449 625 625 443 203 203 114 157 47,716 47,716 37,030 41,240 41,240 51,408 130,994 130,994 133 568 100 152 100,152 244 999 514 080 614680 614,680 380 40,326 54,012 347 496 347,496 347,496 692,771 692,771 692,771 853,906 853,906 853,906 393,622 1.494,128 110695 261,605 164 493 383 105995 685,856 116 067 576252 201,255 355 399 342396 22,611 20.279 888 715,794 377486 33.538482 -------------------------------------------------------------- 794,608 456,280 84,615 276 ========--------------------------------------- PURCHASED POWER & NET INlERCHANGE BPA SI.WIemenlal Cepaclty (331)Bladt Hills Cepeclty 8,546 CoGenIJemes River 356 157MdCol.....e 1 910,672Canadien EntiUement (89 737)CSPE 111,273CoIockum (169,080)GrsnLCOII'Ity 67,600 PGE Cove 24,000 IPC Rellm (78 402) USSR Greensprlngs 80,208F. Conlracts - PP&L 491 165T~SIaIe P\m1ese 275483 South Idaho Ulah to Goshen Ar (455 625) South Idaho BPA to Pacffic 455625 South Idaho Storage 46527 South Idaho Retun of Storage (52,080)APS P\m1ese 3,050T~ Slate Exchange (26685)SCE P\m1ese 36,703BPA Exchenge (223)Avlota P\m1ese 1994 62,600Avlota Exchange (5250)GemSlale 64,730 546 356,157 910 643 (78.033) 856 (189,080) 600 24,000 (76,402) 208 491 165 275 483 (455 625) 455625 46.527 (52,080) 050 703 800 64.730 059 374,549 917,676 (17 592) 083 (174 968) 800 000 (93.727) 55,797 491,165 284 701 (251 807) 425,344 67.922 (86529) 588 12,235 (1) 62,800 65,695 Power Plaming 02120/2002 12:33 PM Page 3 Allach IIPA DR 1.14.xls -1999 GSLM 680 24,680 632 OF Conlracls - UP&L 492 367 492,387 492,367 IPP PU'd1ase 550 718 550718 543.836 Black Hills &.plus 157513 157513 178,989 Roddng PIrc:haso 118224 118224 149480 CoGonIHomiston 847397 871,137 791,939 Dos-' AmusI 009978 009,978 773,700 Dosorot Monthly 193 193 48,948 Dosere. ExpsnsIon 211 073 211 073 228,974 Doserot NF PIrc:haso 217 358 217 358 553 983 APS Exch!rIgo (91 758)(91,758)512) HllrtCOl1e PIrc:haso 889 889 984 Foote Crook 101,899 108,198 121,803 Roddng Exchange 13,085 TIII18AIIa PIrc:haso 258,580 SlF PI6chasos PPL 388 829 12,388 829 12,388 829 SlF PI6chasos UPL 887 903 &87903 887,903 Socondsry PI6chasos 574 505 841,100 115 TOTAL PURCHASED PW & NET 30,470510 29,792,889 789734 COAL FIRED GENERATION Conlrslla 291 787 489936 443218Dave Joimton 870998 870998 887,504 Jim Bridger 452,189 10,453,927 10,480 045 236,940 236,940 245 177 CoIsb1p 022,315 022,315 025 361 Carbon 318,134 318,134 321,978 NIII91ton 338,419 336,524 352,021 HLnlngton 508,544 508 544 525,850 H..,tor 134 808 134,808 289,309 BIInIoII 170 013 170,013 170,496 Cholla 2,378 328 478 819 484,547 Cnilg 340 844 340 844 344,487 Haydon 548 758 548 758 550 485 189 941 225481 225,488 Homiston 819,897 872,882 796,936 PecflIcWostWind Troj8'l TOTAL COAL FIRED GENERATI 51,417293 51,789 185 48,919,858 SYSTEM HYDRO System Hym-o 908,778 007,177 925,&43 DnIII From Storage TOTAL SYSTEM HYDRO 908 805 007 228 925 884 --------------------------------------------------------------- TOTAL RESOURCES 86,794 808 89,45&280 84,815,278 ----------- ------------------------------- --------------------- Power Plamng 02l2Ol2OO2 12:33 PM Pogo 4 Attach IIPADR 1.14.xls -1999 Afetged Sys"'" Adua/12 months ""'*'1112/31199 SPECIAL SALES FOR RESALE Hils So CaI Edison SMUD Sierra Paafic 1 IPI' layoIf Puget Power II Sierra Paafic II UMPA Sale Nevada (Base) Nevada (Poaki1g) CDWR Sale WM'A WM'AII PSCO EWEB 95-.u Sale Oark Sale Iin9on EIack Hils Capacity EIack Hils Slaage SpmgfieId ESI-Kaiser PNGC Choyeme SaleDeoerel ~enl.al Okanogan UMPA II Sale -.. Bedric G&T SpmgfieId II~-BtP Oark- Oark-SEHA Oark- IUricane Sales APPA,AEJ'CO APPA,E1J112 APPA-Mesa atizens Power Green MCUI","", Flalhead Sale BPA WOld Sale Short Term Fm1 Secondary 5*5 TOTAL SPECIAL SAlES 771,134 389387 331 360 102 164 849 801 692,262 768 995 640 096 580 896 585 562 661 391 926 221 201 S50 043 345 082.767 12,801,358 957.973 010747 310 220855 487640 952,059 392.057 999.437 716.753 082638 942,760 616 768 154273 323 228 573 001 416 212 191 100 961,679 714 683 387511 857 824 896 936 260 808 776 187 489409 012 234 886 029080726 Total 497,876 603.982 253 691 567 174 303 693 024 376 172.484 227.281 248 968 510 389 839 322 080,471 932.482 605,150 091 751 630377 764640 290 672,169 143416 378,098 224,946 256000 256 470525 355056 451 108400 269475 116 349 976 217 833 139 485 455 243 401 558 J... 456.421 335480 141,000 362 067 280 786 958 152 064,767 210 507 200 584 531 885 796013 012,909 757050 573,513 051 085 548633 400320 3,795 239996 043408 320 884 043.690 210.000 030 102 302 327 744 027 105 607 258 804 106 198 976 068 340 442 182 278 856 132 122 292 Fob 530,900 265,268 590.640 425 970 151 308 133 456 077 186 208.892 248,286 962 614987 847991 117284 954201 592.982 031 274 095989 764 640 015 215.962 143416 348,568 046,457 122 000 922 170) 261 606 368 712 89,753 110 312 284 881 117 865 432 579 314,762 139 892 242 108 153293 1.271 040 Mar O86 667 040 517,591 430,580 238566 886208 112514 216591 232,168 591 885 832 844 059 260 845430 593 996 960 697 174 916 638.140 440 198 697 108 \*11 554 660 064 108 201 000 039 357.012 181.376 91,333 104,271 283,243 117412 732 (78527) 395808 548338 200370 98,848 120,306 052,163_00____,_- _0000__,- -------- -,-- PURCHASED POWER & NET INTERCHANGE BPA Peak Puchase 73,920000 BPA ~enl.al 36.081BPA EnIi1lern...1 36.081EIack Hils Capadty 1 629134CoGen/J..... River 16.251 444Mid CoUnbia 16,221 401CSPE Grant Ccu1ty 3 086,000PGE Ccwe 224886 USIIR-Fm1 1 046.025 F- eon- - Pl'1IL 49 210896TriState Pu-chase 10,337695 South Idaho Slaage (445770) APS ~enl.al 61 477TriStal. Exchange (295515)SCE Puchase 8,304,417BPA Exchange Avista 5Ionmer Pu-chase 4464.036Avista Exchange (57.750)G... State 2,267.095GSlM 536,957 QF eon- - \PIlL 24.553 955IPI' Layoff 24,848,901 EIack Hils Puchase 96 2,723 673-.uPuchase 2.421,950CoGenlHermislm 70 187,380DeoereIAmual- 17,674,582DeoereIMonHyPuchase 95.386Doserat EJIpansion Pu-d18s 2.023.364Deoeret Non-Fm1Puchase 13,092 543 IUricane - 28 4:15Foote Q-eek Short Term Fm1 Pu'chases 487 752 851 SecondaryPu'chases 62S50 660 773635 160,000 971 971 104372 519086 264,938 223,790 18,961 788 4,703950 888876 (102683) 611 248,050 540,300 (48,400) 193,300 92,728 237 395 303,693 858 197 733 271,364 397 923 705 131 184852 245 197745 190 141 75,213845 160,000 971 971 85.304 375.927 117 126 - 174,650 25,862 056 391448 830 086 183 253,S50 540,300 (210650) 193.300 87.448 009.268 290.786 137 267 222,562 940,712 433,107 62,373 966.893 504 231 473 048889 75.054621 160.000 871 971 823 259 662 286 492 203,630 23.217 106 927 419 427 781 947 609 264,341 770,150 188700 96,536 520,271 151,308 189,570 207,139 931.076 499,405 181,122 36,595 054 28,895 895 797,596 133 931 160 000 352 352 133.501 349.844 395,6&6 259315 961 105801 732,382 608,479 035 (280,500) 000,000) 950 193 300 054 060 655 238.566 171 809 186 875 707 910 289 894 158 379 658 806 782 6&6,838 629,394 AcIueI Net p....,. CostAnalysio ($) Apr 503,222 739811 (127 159) 103 844 213.401 582,602 243 148 217 726 650 880 561 600 279 892 775 912 080 944 329 207 605 150 049150 904 284 770 163907 143416 059043 273 100 836 408418 590 112,514 292 382 121,112 844 280.626 182.335 487.960 376 960 293 280 242 108 239 753 591 043 210.092 348603 160000 352 352 106375 247.387 391 222 326970 158 101379 697,862 803,120 319 (285 120) 193 300 999 168 846 213 401 212,299 221 247 313 785 577 431 130 397 028 669 632 048373 206 249 TOTAL PURCHASED PW & NE --- ------- ------- -- -- 656587 390 143TOTAL WHEBJNG & U- OF F. THERMAL RJB. BURN EXPENSE Centraia Dave JoInIton Jill Bridger Wyodak CdsIJ1! CIobon Naq11on IU1Ii1gIon tOIler BILndeICh* Craig HeydenGadsby Hennislon Foote Q-eek WOldP_W..IWOId Jill Bridger Fuel Credt 878517826 71.334,245 856 048 594 452 111617 211 812,878 786,502 938,789 102,591 S50,902 509,654 696 102 538 943 137 672 942961 11,744 310 791 752 (19 899591) 085.603 435.524 972 089 910 102 191630 704109 653,724 794,915 957,752 774,926 121,604 315,593 441 730 762814 593336 389008 192 758460) 100439 120.597 319327 400823 9.433249 571 688 660,314 739,721 085,376 803737 004,697 291,258 363481 145745 398043 465657 195342 447 788) 915 772 768 006 502.425 279950 974334 602.305 706511 822.063 309593 835.073 742,607 315,231 218.089 259097 217,954 631,713 053 118 (704 819) 69.428,376 698 199 121.043 1,744.827 028.451 629,832 711,774 344,665 055,299 777,675 966,744 297 783 025,854 244,793 325,382 654,609 195.342 778366 079.250 680650 306.769 862.862 406.836 556,45:1 676038 473645 316043 355208 058587 409 121 315296 629,457 (26:1,526)(856.333) May 451 809 371 304 551 788 338 243 312451 324445 097 773 211 562 596 760 767.592 059 260 947 223 590 548 981 790 08:1770 137.026 110.080 974 732 624 100 528 538 402055 763 108215 286.896 117.580 208 028,220 323653 316642 362,530 288328 202.040 184.301 32,800037 722,086 803 048 160000 352 352 214,926 167945 372202 349,860 961 98,528 452.178 808373 756 683 (286671) 289080 700 193300 989.182 312451 432 166 193912 330 719 524366 561 806634 074512 357217 834,310 931 162535 389 999 305.328 565 276 699.832 650 259 237.067 247.462 542.335 312 290 247 652 109 895 479 780 336 023 2,785 723 121 544) JLO1 486 902 714156 698 109 433876 100215 222 193711 225.240 596760 790281 940819 886805 625 024 451 035 580 167 397 960 143 416 227 125 626 200 055 593 678 553 598 103343 113540 296 646 121.112 22.064 073052 407,482 675425 226,471 418994 242.108 008 978070 72445:1 86,544.023 160 000 352 352 107 750 462 076 986 376 359 730 961 86,299 096 212 859059 261 (282 194) 311 651 45,650 206,900 800.685 100215 344455 394,609 421,689 570554 119 031 251 591 53,982486 634 196 597.984 465 583 279400 880 067 655 006 687400 669 125 687 133 588,249 304,824 400 189 315,949 010 771 094 614 627 536 437 730 810 034 565 516) 483291 859525 942 100 473536 118 731 687.640 253.579 227 915 587 243 763 183 174.526 827.963 647 735 128 893 194 365 276.516 143,416 603,358 179452 658 149 320 759375 586796 104 120 114770 308529 121 112 22.960 060492 412.175 493.342 223 554 371.813 242,108 130 817 489 070 596 297 95.326.867 160,000 352 352 191867 393266 295498 334565 18,961 87,337 109865 873479 900 (286440) 025,444 145,200 193,300 132 219 118.731 212 377 209,840 670,938 332.054 166.300 307.609 676 529359 313 844 178.726 818950 785955 674958 280173 783,835 798,991 762,067 415962 112,188 096.029 294.943 954.209 217632 612,747 444932 294762 009930) Aug 460287 837.931 985,460 804 080 213 076 960 104 625 220 042 570.952 798.334 154792 825 989 965 598 114333 843631 330499 110080 677,799 060447 382.639 57.622 642 164 389,636 188,136 103828 106096 282 145 117.560 400 509 289 120409 482 669 344 712 428 977 202 040 229 790 367 971 526 304 110 171 Sop 480056 980994 942848 509625 920 154 142,394 279,322 226.275 595 357 003875 188856 896456 938055 890433 487113 752565 583216 144805 698,946 801,700 930387 997 (848) 483 131 393536 244 114,986 121,260 10.360 103,782 197 744 718,247 243778 271 626 220780 936,896 Oct 101370.841 160,000 352 352 189 867 157 861 105 925 206,500 18,961 671 3,718 570 929965 284,350 436.120 96,995 091.021 920,154 162 735 59,941 756.093 239.793 160485 406,245 004 870 848 243 824 --, 124.772 988.118 486,490 023853 845744 943914 756369 776570 017374 012,895 131883 308.927 950837 052015 551393 351021 464325 406 954) 1.470.117 907 133 099 016 486 280 009 094 043 030 143.049 224,421 551 257 895045 133383 872,806 701,851 961,730 261.633 676320 437,889 110080 671646 304,381 223,670 71.755 371 199 393 536 97,460 109 324 117 560 14.504 406 410 732033 202.040 231.015 707350 228211 --- --- 43.222.418 42,266646 858,228 160 000 352 352 170.088 516.149 287.895 165 480 961 822 908.056 905,692 (85,993) 161,392 282,943 199400 81.818 192,318 009 084 155.918 157,648 745 585 292,080 225,539 82,602 217 609.374 736,016 443649 679426 049273 299,193 167,139 538.224 745006 646.289 649.639 954459 720 308 836 515 298 136 333 617 264 684,417 387522 907 799) TOTAl RIa BURN EXPENSE --------------- ---_h--mm---- --------__--m- ----------- - ------------ ----- --- _--_h__- -----h- --- --- ---- 481 84549472117644,284.065 530669 40.865,244 39.860.516 248,258 page 1 949911 682521 46.429 363 160000 352 352 080 214,579 259.887 248 360 961 292 887.996 874.648 277 (276 859) 143 937 861 94.050 217500 237,868 080213 558,491 163.020 994427 308452 584 898.031 312 642 596 15408:1 755 977 622 831 422.056 670 776 519.417 650 319 747 253 705 490 599 589 571 062 270 557 307 903 486382 203.071 535486 105,864 213580 796,397) Power PIarri'Ig 0212012002 -_u_---------- u_-------u- u_-------- nu--___u __UU__h- --___nnu n--_____--- nn_ _____-- unn_--n- --_--___n_- nnnn--_- - --- -_n_-_---_U_h______- -----u_u_n n___--__-- _nnh__-- ---n__uu --__-__nu _n______--- nn_n____- _nn__h_n -__--__n__- __n--n___- - ----------- Allech IIPA DR 1_14_ NET POWER COST 415462,521 27,O31,b-30,531,860 31.394,401 853 160 946385 754 104 -,,02055 160,491 055 32,009 685 749.692 -------------- ------------- ---------- ----------- ----------- --------------------------------------------------------------------------------------------- ------------- ----------- ----------- ----------- ------------------------------------------------------------------------------ NetP-.reosmwtSysllmLo 10.11. -"." SpIMl At:1uB112 mal'" 0IDJg 12/31/99 Net P- Cast EneIgy AnaIyoio (MWH) Total JIII1 Feb Mil'May J...JLi Aug Sop Oct Noll NET SYS1BI LOMJ 114,946 4.548,015 161 010 4.233,479 I11III.303 612142 077610 633.480 4.548.222 019,257 101 033 4,266,431 SPECIAL SALES FOR RESALE -... 539142 45,464 447 664 609 962 716 331 866 641 650 634So CaI Edson 1,222,482 94,324 075 624 106 915 103681 94,280 102204 110573 111144 117 566 115128SMUD55172330561971823446,600 37,639 620 442 221 57,483 74,967Sierra 589,046 52,738 39,376 021 951 50,283 967 50,085 52,583 55,801 54,040IPP Layotf 550 716 807 269 918 264 992 242 949 44,660 46,863 924Pugot 048435 050 985 200 600 900 700 000 600 100400 104160 450Sierra- II 460 314 012 471 34,225 36,370 745 475 41,300 935 991 498 224UMPA Sale 827 698 943 321 687 718 441 720 844 479 768 682Nevada (Base)181 150 37.200 600 150 35,950 250Nevada (PeaIci1g)440 440 COWR 608418 44,400 47,978 130 704 000 52,000 52,000 410 50,400 51.913 46,179WN'A 380 765 706 31,283 765 698 381 28,648 29,701 761 785 556 33,041WN'AII 630 620 794 52,345 54,000 956 000 42,758 043 010 796 886P5CO1.168 033 100516 263 101,909 932 199 047 97,566 100226 685 205 698EWEll 95 301 615 320 760 720 320 600 23,300 250 715 250 835Redding Sale 379 626 469 712 283 25,584 513 014 36,800 37,057 000 600 654Oork Sale 221 360 151662 134340 687 68,233 450 800 360 46,360 920 168498 163 800956,989 163,680 147840 163 680 158,180 163 155 159 840... Capac:ity PIarri1g 02l2Ol2OO2 AItad1I1PADRI,14.J11s Black SIcnIge SpmgIieId ESI-Kaiser PNGC Cheyeme Sale Deserel SUpplementDI Okanogan UMPA II Sale Plan BecIric G&T SpmgIieId II CowiIZ-IIII' OartI- OartI-SEHA OartI- Ibricane Sale APPA-AEPCO APPA-ED112 APPA-Mesa Citizens Power Gr.... MCUlIainsFIa- Sale BPA Wild Sale Short Term Fm Secondsry SMs TOTAL SPECIAL SAlES 210 169345 876000 283,375 935,045 449,526 47.467 548 251,048 145 600 186 81.849 171.369 771 925 203 716 240 130994 100152 514,080 360 18.894173 561 467 883.435 3.- 27.285 74,400 520 799 735 580 956 20,800 630 745 974 118 642 395 702 005423 213 849 580 914 345 325 67.200 800 625 417 704 200 612 527 145 432 382 560 608 585 908 145 122 829394 365 680 400 600 808 519 167 (65) 127 600 011 903 053 221 444 688 599 080 665310 118211 018 872 040 572 900 32,000 762 25,000 380 601 400 129 465 860 190 419 13.410 419 330 476 770,613 114,522 628 400 205 49.749 307 737 528 022 504 440 523 439 7.439 000 800 919 080 580 936607 65.720 896 72.000 71.071 606 088 888 22,352 536 753 737 200 68B 169 169 320 310 877 400 752 552 174 121625 924 74,400 276 235 646 766 484 884 084 19.738 440 769 21,997 468 8.280 690 706 080 548 381 388 136,228 181.326 ------ 7.320,545 183 023 179949 749966 fi87O55 10,885 400 760 775 151 200 28,181 23,494 929 148 612 440 820 210 747 320 591 282 52,080 279 378.017 222.212 852 966 245 72.000 39.800 75,912 60,575 816 23,826 455 400 912 633 18.745 200 800 369 906 320 11,280 928 50.400 669 212410 175759 685.fi81 25,037 74,500 40,975 313 088 172 (48) 23,171 20.800 559 980 450 370 1.969 800 082 150 337 520 785 74,397 130,247 13,593 72,000 39,200 75.929 818 752 341 20.800 514 598 200 518 13,800 13.109 50.400 689 534 325 161 058 617 -------------- ------------ ----------- ----------- ----------- ----------- ----------- ------------ ------------ ------------ ------------ --------------------------- ------------- ----------- ----------- ----------- ----------- ------------ ------------ ------------ ------------ ------------ ------------ 7.325,048TOTAL REOUIRe.lENTS 67.068,381 128 829 090394 7.252.351 982691 827476 401,208 714948 7,231,280 --------------- ------------- ----------- ----------- --_n_____- __n______ - ------------ ------------ ------------ ------------ ------------ ------------ --__d__--_--_- ------------ ----------- ----------- ----------- __n______ - ------------ ------------ ------------ ------------ ------------ ------------ PURCHASBI POWER & NET It.lTERCHANGE BPA SUpplemental Black_Capacity CoGen James River Mid CcUnbiaear-. EnIiIIemen! CSPE Grant CoUIty PGE Cole IPC Rabon USBR F. Cmtrads - PP&L TriStataPu'dme South Idaho APS SUpplemental TriSlata Exchange SCEPu'dme BPA Exchange Avista SIonmer Pu'dme Avista Exchange Gam Stale GSLM QF Cmtrads - 1P&l IPP Layolf Black Pu'dme 96 RedOOg Pu-cheseCoGen/Hennistm Deserel ArruaI Pu'dme Deserel Monthly Pu-chese Deserel 8Ipansion Pu'dme Deserel Nm-Fm Pu'dme APS Exchange Ibricane Pu'dme Foote O'eek Short Term Fm PLrcheses Seccndery PLrcheses TOTAL PURCHASBI PW & NET COAL ARBJ G8IIERATION Centrale DeveJoIw1stm Jin Bridger WyodakCob"" Cerbm~tm IU1IO1gtm a.. Craig Gedsby Hermistm PecificWeslWIId TKjan TOTAL COAL ARBJ G8IIERATI TOTAL SYSTH.1 HYDRO TOTAL RESOURCES (331) 546 356 157 760591 (69 737) 111 273 (169080) 600 000 (79,402) 80,208 491 165 2754&3 553) 050 (26,665) 703 (223) 82.800 250) 64.730 680 482,367 550716 157513 118.224 847397 009,976 193 211073 217 358 (91759) 889 101.899 074 532 207 633 953,547 145 944 233.793 605 981 260 895 136757 220 255 703.429 131471 031 601 155529 533051 391 605 537364 363093 847356 259 (536) --- 51,280,646 823 988 068 381 33,291 251,989 (3,820) 16.908 (17 179) 394 028 211) 345 49.335 594 (8,934) 550 400) 215 40,974 807 330 653 176.972 137.024 081 825 600 101 545,761 316.195 (420) 154 242922 (3,450) 271 (15,740) 990 884 469) 613 46,955 21, (62) 300 23.050 (19 150) 975 823 077 725 665 156,704 992 638 108 622 27,419 287341 262,359 132 606 266,247 778) 391 (18.110) 818 028 (8,610) 014 552 993 141 031 (23) 388 074 269 649 114 150,199 680 654 937) (22) 697 782 246,957 787.436 --- 647 328 326,739 530744 986566 202866 669 108855 393,410 605796 795872 906 228.039 116489 932 14.042 177359 (59) 650 526 690 967 ----------- 128829 2,371 312 334 235 418 650 810574 117 520 266 100 084 393.958 591 742 684 505 209 215 255 109 104 43,154 024 156.703 (52) 139931 579 151 090 394 252 756 359.663 882 194 198 897 632 118 683 407 805 643293 448311 169 219164 116056 161 345 150 198 (55) 957,281 647 732 570 578 225575 448) 651 (11 371) 409 978 (9.913) 120 178 4&2 010 (25500) 450 108 957 553 44,919 460 123 147 590 697 17.416 111 684 781 051 513 827 (249) 455 27.337 196285 (6,520) 883 292) 342 028 941) 000 40.950 112 377 (25920) 452 909 34,524 57,264 12,585 801 138001 139 14.561 (105.932) (76.156) 012 964400 336467 330 517 25,596 269,014 (6,452) 661 (225) 99& 980 563) 662 37,091 458 216 750 (26.061) 000 700 15,168 44,149 992 055 10,707 108635 107 16,767 451 (142 040) 593 692940 258.659 947,365 ------ 2.594,952 353524 268,687 712,259 190.335 101.505 51.221 347737 550,352 641063 047 217,759 117,001 767 454 147590 (46) 769,254 464 707 672925 346328 342,066 669,535 139 106 69,028 59,001 232,879 630,516 591.994 708 161.746 122,608 34,743 919 136 079 (42) 128,861 492,732 901 707 181000 910 100637 303.116 546465 472.970 12.989 208,394 111,778 199 577 109,977 (37) (200) 32,042 279,397 690) 098 (12361) 278 028 794) 863 440 22.797 559 (25.654) 696 12,746 150 15,399 54,171 242 305 12,905 145454 99,746 15,785 51,298 (142,360) 175 993 1.490661 173,164 (190) 534 230.545 521) 098 (15484) 559 028 (6,756) 828 590 747 257 (26 040) 332 13.200 603 45,573 46,849 320 597 165 193 117 15,291 293 (142786) 402 560 268 136,966 140 618 186,095 (6.452) 661 (20.352) 096 980 238) 809 30,273 23,824 936 (25 169) (33 120) 16,722 550 035 660 670 001 160.654 74.769 433 231 (69040) 649 094,291 243,512 (85) 397 375 164,959 525) 992 (25.975) 900 030 060) 828 39.795 27.468 1150 096 (34 376) 44,193 46,863 720 310 173.919 70.845 19,895 28,171 336 373 359.516 264.722 661 33,227 199,492 453) 661 (12 101) 728 980 722) 993 41,557 25,869 479) 672 19,259 (32400) 719 753 824 430 705 165.687 934 527 361 138 240 562 517 235 222.434 451 933 ------- ------- ----- --- 2,536,438 339,074 529,763 904 111 199,601 82,152 108,061 395,614 655,079 652.963 12,842 224,133 111.191 53.066 49,337 145,518 757 (38) 349 487 367 810 519,814 959 817 201 737 101,963 121,336 442,863 663.955 759594 13,108 224 916 121,415 50,337 994 165316 751 (36) 821 396 413 086 423,734 931 781 198 749 728 115.226 432,788 602,401 755,498 171 175.781 114.754 254 28,107 161.542 618 (35) 777,214 542 752 -- -- ----, --- 4.510 193 283,369 746 906 493 718 463,214 405.398 756770 294.951 375,392 431,310 396,155 793282 204566 106,033 129,336 467378 537.312 807,691 13,651 194,299 109,955 49,098 65.321 175,191 498 (39) 461.037 374.861 430.212 437798 987426 179 318 621 104 664 447 198 514.870 680.371 958 224 493 111 213 134 229 163 971 396 (44) 4.357.818 428792 -- --- ---- ---- ------ -------- ------- -- --- ---- ---- ------ -------- -------- 7.325,0487.252 351 181.326 982691 827 476 320,545 401,208 714.948 7,231.280___n___--__--- ------------- ----------- ----------- ___n_____- ----------- ------------ --__n_--__- ------------ ------------ _--n______- --__n_____- --------------- ------------- ----------- ----------- ----------- ----------- ------------ ------------ ------------ ------------ ------------ ------------ Power Planning 0212012002 pogo 3 AIlachIlPA DR 1.14Jds Dee 479,157 106,763 936 276 502 965 111,289 076 786 026,837 223,644 633924 825829 189,046 967733 742,165 090,087 163 095 122 567 119 143,416 698,100 305 966 582 192 391 556 482 104 361 115193 121 112 644 4iO,598 634381 242 108 315 029 36,659,717 443514 81,544,913 160000 352 352 162,081 587878 1.448 154 213 150 961 156 162,850 973 971 (410251) 190 586 733 461 (107 250) 197 800 'S74 114 228 111 289 132758 207425 103081 209713 386 538) 364461 418 983 'S73 238,210 495 651 6.512 921 977 088 470,655 636,090 629 207 774 139 612,802 630,289 380,563 128 584 311 44& 959 432 853 076 574 920 928 041 283,344 (3,260,535) ---- 41,1199,719 ------------------------ Paoer PIarn1g 02/2012002 page 4 AItad1I1PADR 1.14.xIs 34,363.384 ----------------------- Doc 785 154 S48 118068 63,886 224 951 100,390 168 648 304 430 800 102 'ET775 940 168 260 614 PIMB" PIsrD1g 02l2Ol2OO2 AIIach IIPA DR 1.14"" 275 400 920 570 635 655 730 600 943 991 440 423 640 923 52,080 030 1.351 153 662 816831 ---------------------- 601,985 ------------------------ 781 799 258 264 628) 098 (11 990) 090 028 (7,125) 033 449 367 (35 674) 326 300 750) 517 945 46,851 265 11,453 158 489 126 193 025 378 142,848 107 213 183283 212, 305 883 422,009 513,997 967669 187200 104050 104 151 438683 599690 779 052 239 083 120 021 519 24,744 157 912 197 (54) 678 702 617 590 601 985 ------------------- Power I'Iarr81g 02/20/2002 Attach IIPA OR 1.lbls P& G / t I G o I J I Ac t u a l Ad u s l 1 2 m o n t h s o n d l n g 1 2 1 3 1 1 0 0 Ne t eo , t A n a l p i s ($ 1 20 0 0 Ja n Fo b Ma r Af J r Ma y J. . , Ju l Au i J Se p Oc t No v Do c SP E C I A L S A L E S F O R R E S A L E Bla c k H i l i ' 82 1 92 1 23 1 58 5 19 7 38 5 23 7 . 89 5 21 9 . 29 2 22 o . e 3 8 20 4 . 30 2 21 1 . 97 1 20 7 . 74 9 20 4 , 85 0 1.2 5 3 . 38 1 20 8 . 50 3 22 4 . 57 5 So C a i E d I , o n ( P I 29 , 25 7 , 77 2 52 4 . 85 9 38 3 . 39 2 27 7 , 27 1 23 3 . 58 4 28 7 . 18 8 33 4 . 98 9 53 5 . 48 7 59 2 . 57 7 49 8 84 9 49 5 , 22 1 49 7 . 35 1 81 9 , 28 9 So C a l E d i s o n ( U I 29 , 25 7 , 77 2 52 4 , 85 9 38 3 . 39 2 27 7 , 27 1 23 3 . 58 4 28 7 18 8 33 4 , 98 9 53 5 . 49 7 59 2 , 57 7 49 8 , 84 9 49 5 . 22 1 49 7 . 35 1 81 9 28 9 SM U D 83 7 . 94 1 89 4 . 34 8 75 0 , 78 8 34 5 , 89 4 (3 e 1 I , 83 3 1 45 4 , 57 7 19 0 , 29 4 78 2 , 43 4 94 7 , 41 9 02 7 , 82 0 11 4 9 , 38 5 70 1 08 4 20 3 . 75 3 IP P S a i e 23 . 18 5 38 3 11 3 , 08 1 08 0 . 48 5 98 2 , 52 2 78 3 , 48 9 04 1 . 70 1 12 8 . 98 7 12 7 . 81 9 11 8 94 2 58 1 , 83 5 12 3 . 99 1 09 1 , 24 2 07 5 30 9 pu g e t P o w e r I I 49 , 01 8 , 28 8 29 3 , 34 0 17 7 , 45 8 78 9 . 50 0 83 9 , 10 0 92 1 41 5 98 8 , 22 0 05 5 , 39 5 19 5 , 18 4 08 2 , 83 7 05 3 . 57 0 90 8 , 94 8 97 5 , 4 2 3 Sie r r a P e c I 1 I c 38 1 . 80 1 50 4 , 37 4 48 4 , 34 4 50 9 . 33 5 49 9 . 97 2 41 2 89 0 08 8 SI e r r a P a c l 1 l c I I 19 0 38 4 82 4 . 42 4 75 0 , 74 4 75 8 , 11 7 71 3 , 47 2 82 8 . 08 1 77 4 , 81 2 74 9 , 30 8 77 3 , 82 9 89 4 . 43 3 77 8 , 08 1 81 8 , 84 3 73 0 , 88 0 UM P A S a i e 37 7 . 51 3 19 1 77 5 18 3 . 77 3 18 7 , 78 3 18 0 , 53 8 18 2 . 09 0 19 1 , 47 3 22 2 , 25 8 19 9 , 07 4 20 3 . 75 8 20 7 . 13 5 21 4 54 1 21 3 . 33 7 Ne v a d a ( b a s e ) (4 4 , 88 7 ) 23 . 42 5 (8 8 , 50 0 ) 81 2 ) CD W R S a l e 31 . 11 9 . 79 4 82 7 90 8 82 0 . 18 0 88 8 , 38 9 82 2 , 22 9 02 5 , 74 2 81 3 , 32 0 82 0 , 18 0 82 7 , 00 0 59 3 , 70 8 82 8 , 29 2 70 0 , 25 8 75 4 , 83 4 WA P A S a i e 17 , 80 8 , 53 8 83 1 . 02 8 89 1 . 8 3 8 89 5 74 4 88 1 , 98 8 57 9 , 15 8 87 8 , 22 7 72 1 . 87 9 97 4 , 74 4 84 0 , 79 7 81 7 . 97 1 08 9 , 10 3 42 8 . 48 3 WA P A I I S a l e 13 , 12 4 . 79 3 20 2 30 0 13 3 . 30 5 95 2 91 4 92 3 . 49 5 88 9 . 80 0 57 7 , 08 4 22 5 . 13 8 20 2 , 30 0 18 7 , 81 2 20 3 . 73 7 18 7 81 2 32 0 . 88 2 1 PS C o S a l e 47 . 28 2 . 19 7 11 0 . 37 7 00 8 , 81 0 01 5 . 02 4 08 2 , 49 3 39 8 , 14 4 11 8 07 2 12 0 , 53 7 08 8 , 27 9 95 4 , 95 8 19 8 , 08 4 09 9 34 8 09 2 . 30 3 EW E B S a l e 9 5 10 9 . 05 8 89 2 . 30 0 88 8 . 08 8 93 4 . 89 9 84 1 . 4 8 5 90 3 . 72 9 91 3 08 0 93 7 , 49 7 Re d d i n g S a l e 10 , 58 8 , 54 7 07 9 , 72 4 99 9 58 5 99 5 84 3 93 8 . 85 3 97 9 17 8 95 2 , 51 0 09 9 . 39 3 41 7 , 72 4 17 3 , 18 2 97 9 , 19 1 94 1 . 58 8 Cla r k S a l e 32 , 24 0 24 3 18 3 , 0 9 5 98 9 . 70 1 58 8 , 38 7 42 2 , 74 1 72 8 . 77 1 02 3 , 09 8 97 9 , 25 7 18 3 , 93 7 03 7 , 83 8 43 7 . 22 2 40 9 , 41 3 33 7 , 00 3 Hin s o n 12 , 57 4 78 3 (1 4 , 12 2 ) 53 7 . 78 8 85 9 88 4 80 4 , 09 9 12 9 . 39 2 02 5 , 08 7 33 2 19 3 30 0 51 2 Bl a c k H i l l s C a p a c i l y S a l e 79 2 84 0 15 0 00 0 10 0 , 52 8 22 2 , 13 3 75 , 00 0 24 5 , 17 9 Bl a c k H i l l s S t o r a g e 28 , 10 0 08 0 54 0 19 . 50 0 Sp r I n g t l e l d 88 3 , 14 0 54 8 82 7 82 0 , 49 2 83 3 42 7 49 8 , 84 8 32 9 82 0 19 2 , 42 8 29 0 , 71 1 27 1 , 71 0 08 5 98 9 52 8 , 08 9 88 0 . 87 2 21 4 , 58 9 PN G C 37 0 , 82 2 69 8 , 10 0 85 7 , 4 9 8 89 8 , 10 0 55 2 88 2 78 1 , 58 3 73 9 41 8 78 2 , 48 8 73 9 41 8 78 1 , 58 3 Ch e y e n n e S a l e 28 , 65 8 , 49 4 27 7 , 74 4 14 2 28 9 22 7 , 82 8 10 4 45 4 18 4 , 40 8 11 3 . 99 3 31 2 29 0 31 5 , 55 9 18 3 , 38 5 15 3 , 45 0 28 5 , 28 1 37 8 07 3 De s e , , ! S u p p l e m e n t a l 32 . 03 3 . 95 7 55 5 . 57 4 89 4 , 01 4 38 7 , 46 3 37 4 , 37 8 78 2 , 58 4 53 1 , 88 8 09 9 , 98 4 52 3 84 9 82 3 14 9 (1 4 5 ) 00 9 , 39 4 10 . 07 2 . 04 8 OK a n o g a n 70 8 , 95 2 85 , 39 1 82 4 84 , 03 9 52 , 12 5 35 , 95 3 81 8 17 2 49 , 43 7 70 9 58 , 24 9 85 . 23 2 78 , 40 8 UM P A I I S a l e 89 2 31 3 40 9 78 0 05 2 , 51 1 12 4 , 78 1 98 8 . 07 9 04 3 (2 1 8 ) 35 7 Pl a i n s E l e c t r i c G & T 72 3 , 85 5 78 2 03 5 58 4 79 4 72 8 . 11 2 88 1 , 85 3 90 9 , 29 2 85 9 , 58 9 Sp n n g 1 l e l d I I 70 7 . 83 2 38 2 38 0 35 5 , 40 0 38 3 , 83 2 18 0 , 90 0 18 9 . 80 0 41 1 84 0 41 1 , 84 0 41 1 , 84 0 Co w l l t z - BH P 18 7 , 87 5 10 4 81 4 95 , 18 4 10 8 . 58 2 10 2 . 57 0 10 9 , 98 0 10 5 25 4 10 7 . 88 8 10 4 . 98 3 83 , 99 9 18 0 94 , 52 5 17 8 Cl a r k - F W 91 5 , 54 5 11 4 , 08 8 10 8 . 45 8 11 0 , 85 3 10 5 . 90 7 10 9 . 88 3 10 8 52 8 11 0 , 48 4 85 , 72 2 04 4 Cl a r k - W T 43 2 . 03 2 12 1 , 11 2 11 4 . 00 8 12 1 11 2 11 7 . 41 2 12 1 , 11 2 11 7 , 58 0 12 1 , 11 2 12 1 , 11 2 11 7 58 0 12 1 , 28 0 11 7 58 0 12 1 , 11 2 Hu r r 1 c a n e S a l e s 21 9 , 85 8 11 , 53 8 11 , 42 4 12 , 51 8 13 , 04 8 18 , 82 8 19 , 71 2 21 , 88 8 40 , 82 4 30 , 83 2 18 8 70 8 18 , 59 2 AP P A - A E P C O 88 7 80 9 55 5 , 73 8 38 8 , 40 5 49 5 . 42 0 49 0 , 29 4 75 9 75 4 AP P A - E D # 2 93 9 28 2 10 8 , 74 5 11 0 21 8 28 1 , 42 4 40 4 , 93 8 40 4 . 28 9 40 3 , 95 1 12 5 , 31 2 10 2 , 42 6 AP P A - M e s a 53 8 57 5 51 1 , 85 1 50 5 , 94 8 50 1 , 38 1 51 1 , 85 1 50 5 , 94 8 Cit i z e n , P o w e r 11 0 22 4 33 3 , 47 2 37 5 . 15 8 29 7 91 8 37 7 . 14 8 42 8 , 34 2 33 0 , 71 3 33 3 78 8 22 7 . 87 2 22 5 , 94 4 45 3 . 41 4 37 4 , 14 3 35 4 . 31 4 Gr a e n M o u n t a i n s 30 , 75 5 73 7 81 5 , 01 7 89 5 , 41 9 54 2 , 02 1 80 0 , 59 1 13 8 , 89 1 07 7 . 94 8 98 2 . 20 0 58 8 , 78 8 70 2 , 34 5 84 4 , 84 4 58 8 , 27 1 20 1 80 4 Ra l h e a d S a l e 14 , 88 4 88 8 24 2 , 10 8 18 1 97 2 24 2 , 10 8 20 0 , 37 0 24 2 , 10 8 20 2 . 04 0 24 2 . 10 8 24 2 , 10 8 20 2 04 0 24 3 , 77 8 20 2 04 0 24 2 . 10 8 BP A W I n d S a l e 08 7 , 15 1 34 9 , 97 8 30 3 , 75 8 23 8 , 17 8 20 9 58 0 44 9 , 90 0 18 3 . 00 8 10 7 . 85 9 14 9 , 94 5 21 0 , 17 9 . 25 2 31 3 , 92 7 39 4 11 2 SD G & E S a l e 42 8 , 84 9 22 3 . 88 0 14 4 , 92 0 22 3 88 0 18 2 , 75 5 22 9 , 70 7 17 1 77 9 22 3 88 0 22 3 . 05 8 18 4 , 81 2 22 4 70 3 17 5 . 40 2 21 8 , 07 3 Sh o r t T e r m F i r m S a l e s 18 5 , 53 8 , 17 8 26 , 88 8 , 41 8 28 , 74 2 , 85 2 35 , 44 4 , 37 2 29 , 48 7 81 8 38 , 98 7 , 12 5 99 , 87 7 , 59 7 91 , 82 9 , 01 5 15 3 . 28 0 , 97 0 13 2 , 54 0 , 88 2 18 0 , 08 2 , 53 2 19 5 , 85 2 , 95 0 18 7 , 00 3 , 88 9 Se c o n d l l l Y S a l e s 21 , 51 1 . 9 3 1 09 4 , 49 3 47 7 , 24 3 81 2 , 75 7 04 2 , 39 3 20 8 , 98 3 51 8 , 57 0 23 2 , 30 3 13 4 , 47 1 15 4 . 18 0 01 5 , 53 9 78 9 , 15 4 25 3 88 5 TO T A L S P E C I A L S A L E S 70 5 29 3 , 45 3 74 , 38 1 , 41 5 72 , 22 2 ' 77 5 78 , 19 9 , 40 7 87 , 28 3 . 28 8 82 9 , 98 4 13 4 . 99 2 , 59 9 13 7 . 85 1 , 13 2 20 4 . 80 3 , 75 7 17 7 , 72 0 , 47 9 20 3 , 98 1 , 18 2 24 0 , 17 3 , 12 8 23 5 , 11 4 , 38 9 'U R C H A S E D P O W E R & N E T I N T E R C H A N G E BP A P e a k i n g P u ' c h a s e 04 0 , 00 0 18 0 , 00 0 18 0 , 00 0 18 0 . 00 0 18 0 00 0 18 0 . 00 0 18 0 , 00 0 18 0 , 00 0 18 0 , 00 0 18 0 , 00 0 18 0 00 0 18 0 . 00 0 18 0 . 00 0 BP A E n t i t i e m e n l C a p a c i t y 28 , 84 9 35 2 35 2 35 2 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 BP A 5 \ 4 ! p l e m e n t a l C a p a c i t y 84 9 35 2 35 2 35 2 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 Bla c k H i l l s C a p a c i t y P u r c h e s e 54 9 , 78 8 18 7 , 10 5 10 8 , 18 3 82 5 97 , 32 7 14 1 , 59 7 17 4 , 48 0 28 2 , 39 9 88 , 39 9 11 9 , 81 2 78 . 15 7 75 5 12 8 72 7 Co G s n / J a m e s R i v e r 72 5 , 14 0 88 0 . 70 7 51 7 , 71 7 40 4 , 88 2 41 2 42 7 13 3 , 13 0 44 1 . 38 9 49 9 . 70 2 38 2 . 89 9 22 0 , 49 5 38 7 . 00 8 34 8 , 50 8 31 8 , 51 5 Mid C o i L m b i a 31 3 . 84 9 32 8 . 91 2 28 2 , 7 4 2 43 1 , 82 4 81 9 47 5 87 9 , 09 7 38 7 . 51 7 38 7 15 1 35 0 79 5 88 4 , 52 4 08 8 , 19 7 57 1 . 0 0 7 38 8 , 40 7 Gr a n t C o u n t y 08 8 . 00 0 22 3 , 79 0 17 4 , 85 0 20 3 83 0 25 9 , 31 5 32 7 , 02 0 34 9 , 81 0 35 9 , 73 0 33 4 , 58 5 24 8 , 38 0 20 8 . 50 0 18 5 . 48 0 21 3 , 15 0 PG E C o v e 23 1 71 8 98 1 14 7 98 1 18 , 95 1 18 , 98 1 18 , 98 1 18 , 98 1 18 , 98 1 18 . 98 1 18 , 98 1 18 . 98 1 18 , 98 1 US S R G " e n s p n n g s 78 8 , 54 2 77 8 82 , 30 8 98 , 58 4 79 . 15 4 93 , 20 8 58 0 74 , 17 5 10 0 , 11 1 82 , 37 2 15 , 29 8 F. C o n t r a c t s - P P & l 52 , 17 7 09 5 34 8 20 9 90 2 . 52 0 59 5 , 48 4 84 0 , 97 1 55 0 45 7 23 7 71 0 98 1 , 01 3 84 2 87 7 28 7 . 48 1 87 8 , 37 8 21 9 25 0 11 4 93 5 Tn S t a t a P u r c h a s e 10 , 38 4 , 57 2 00 0 , 84 4 99 3 . 57 9 98 0 , 97 5 95 8 , 93 2 98 0 , 11 9 84 4 , 09 2 82 7 , 97 7 88 2 28 1 29 2 . 79 3 18 1 , 13 8 74 3 33 9 73 0 , 52 5 So u t h I d a h o E x c h a n g e (1 8 5 , 11 2 ) (4 7 . 18 8 1 (9 8 , 17 8 1 (1 7 , 98 8 ) (4 , 39 2 ) 24 9 80 8 ) (4 9 ) AP S P u r c h a s e 22 0 , 48 0 25 , 58 0 29 3 14 9 , 4 5 8 (1 4 3 . 83 8 1 45 0 , 53 4 18 7 , 09 3 19 8 71 4 51 2 , 77 0 80 9 , 00 3 22 9 , 87 3 Tn S t a t e E x c h a n g e SC E P u r c h a s e 38 , 89 0 , 09 7 88 5 , 20 7 80 3 , 80 0 (1 9 8 20 0 ) 04 8 , 58 8 17 . 55 9 . 82 9 14 , 19 3 , 07 3 Av l s t a S U m m e r P u r c h a s e 09 7 , 91 7 90 3 80 5 18 3 41 0 52 4 35 0 08 0 , 91 8 42 5 , 43 8 Av l s t a E x c h a n g e Ge m S t a t e 58 5 10 1 38 9 , 40 0 20 0 80 0 19 8 20 0 19 8 . 20 0 19 8 , 20 0 19 8 , 20 0 20 1 , 50 0 19 8 , 20 0 22 8 . 80 0 14 4 , 0 0 1 21 0 80 0 20 9 . 20 0 GS L M 40 0 , 48 7 81 , 82 0 15 , 31 2 82 , 49 9 38 , 35 4 49 . 38 9 54 , 72 9 78 , 57 2 QF C o n t r a c t s - U P & l 89 7 , 45 7 22 5 , 89 5 15 4 , 49 2 28 3 , 80 2 92 9 53 5 18 0 . 00 4 27 3 88 9 43 9 , 87 5 45 3 , 84 8 29 8 01 1 71 4 , 88 9 37 4 34 8 40 9 92 1 Po w e r P I . . 20 1 2 0 0 2 Atb JR 1 . 14 . )( I s IP P P u r c h . . e 23 , 18 5 , 36 3 11 3 06 1 06 0 48 5 96 2 , 52 2 76 3 , 46 9 04 1 , 70 1 12 6 96 7 12 7 , 61 9 11 6 , 94 2 56 1 , 63 5 12 3 , 99 1 09 1 , 24 2 07 5 , 30 9 Blo c k H I l i . S U r p l u . 18 2 , 69 4 11 7 , 79 2 58 , 36 6 17 6 , 46 3 29 6 , 34 5 42 0 77 6 31 4 , 64 7 41 9 , 78 5 97 3 31 2 11 9 , 44 1 68 5 , 40 8 90 3 , 35 9 69 6 , 62 0 He r m l . t o n P u r " " . . e 74 , 05 7 17 4 69 9 05 5 61 9 04 1 59 3 00 0 95 8 03 8 92 7 81 4 13 1 , 96 9 28 5 , 03 9 27 4 , 56 3 18 5 00 0 25 1 90 5 24 8 , 00 0 68 3 , 95 0 Ce . e r e t E x p a n s i o n 40 7 , 57 2 88 8 18 6 84 8 10 7 61 4 79 3 17 1 , 33 7 11 4 , 92 7 14 4 , 00 0 67 , 63 4 12 1 , 83 1 11 8 , 0 3 2 12 2 , 00 0 10 8 , 69 0 Ce . e r e t R e . o u r c e P u r c h . . e 15 , 88 5 , 26 9 39 5 22 4 03 8 , 17 5 39 0 . 0 2 7 01 3 59 9 70 1 98 2 46 8 , 27 9 09 7 , 91 3 07 8 , 56 8 33 8 , 10 9 38 0 , 49 2 22 8 , 87 1 (5 , 23 9 , 77 0 ) Hu n 1 c s n e P u r c h a s e 28 , 73 6 45 2 00 1 32 3 76 3 88 2 88 2 12 0 20 1 28 1 83 2 19 9 LT F R e . e r v e P u r c : h a s o a 06 9 50 0 50 0 59 , 50 0 59 , 50 0 28 9 , 34 5 17 4 , 50 0 17 4 , 50 0 15 9 , 85 5 17 4 , 50 0 19 9 , 00 0 19 9 , 00 0 19 9 , 00 0 32 1 50 0 Tr a n a A J t a Pu r " " . . e 57 , 83 9 , 25 9 10 , 58 7 , 4 9 2 10 , 58 7 49 2 10 , 09 3 , 78 9 11 7 44 8 87 8 , 90 3 77 4 , 13 5 Fo o t e C r o o k I V P u r c h 10 1 , 52 0 10 1 , 52 0 CS M ( L o a d C u r I 8 I l m o n t ) 40 2 , 59 9 40 2 , 59 9 Sh o r t T e r m F i r m P u r c : h a s e . 39 7 , 16 3 , 14 7 25 , 50 5 , 10 0 24 , 20 9 12 6 29 , 48 6 , 80 8 20 , 81 1 73 4 45 , 55 2 , 44 1 13 0 , 47 2 , 59 5 15 2 , 94 9 , 67 3 20 2 , 32 7 , 91 2 14 8 , 11 7 , 43 5 15 3 , 20 8 , 58 6 19 7 , 64 2 , 12 6 29 7 , 22 1 , 81 1 Se c o n d a r y Pu r " " . . . . 99 , 35 3 , 90 5 57 7 , 19 7 66 7 16 4 10 0 , 93 0 62 1 , 77 8 22 9 , 84 0 59 2 , 35 0 31 6 , 89 4 11 , 02 7 , 70 0 13 0 , 88 8 83 5 , 94 5 11 , 48 5 , 57 5 78 7 , 84 8 TO T A L P U R C H A S E D P W & N E T I N T . 95 5 , 74 2 , 92 5 57 , 88 3 , 13 7 55 , 38 5 , 03 1 59 , 27 0 , 19 8 33 2 , 17 8 77 , 58 8 , 3t1 6 17 0 , 43 4 , 91 5 20 1 , 88 7 , 92 8 25 8 , 96 3 , 38 8 19 4 , 78 9 38 2 20 0 , 57 7 , 80 4 27 5 , 74 4 , 23 8 3& 0 , 12 8 , 22 3 TO T A L W H E E L I N G & U . O F F . E X P E N S E 94 , 97 1 , 82 8 24 0 , 99 5 28 1 , 55 7 24 5 , 27 2 78 0 , 41 9 44 0 , 15 7 38 8 , 72 3 89 8 , 89 0 93 0 , 97 1 85 9 38 8 20 , 98 7 , 99 1 85 8 , 92 7 10 , 09 8 , 55 8 TH E R M A L F U E L B U R N E X P E N S E Co n l n l l i a 45 8 53 0 43 7 , 64 0 86 3 35 1 53 7 , 42 1 80 2 , 65 8 01 7 26 0 Ca v e J o h n s t o n 19 7 , 80 9 08 3 , 77 3 29 2 , 66 7 00 7 , 05 7 94 2 , 92 8 47 3 25 0 38 3 02 2 , 13 1 19 3 34 1 45 1 , 14 5 59 3 , 11 4 74 8 , 64 1 15 8 , 83 3 Jim B r i d g e r 11 0 38 2 , 32 4 81 0 , 23 1 88 2 07 0 24 3 , 70 5 31 6 01 8 79 6 71 5 07 2 , 42 3 51 9 97 2 9, 4 2 5 , 59 0 10 , 14 2 , 99 7 87 9 , 88 5 27 9 , 82 8 21 1 , 09 2 Wy o d l l k 19 , 81 9 08 5 82 2 , 39 4 71 8 , 48 3 66 2 , 84 5 75 5 95 2 34 0 , 30 2 28 9 , 24 4 71 9 , 98 5 95 0 , 36 5 76 7 35 8 83 6 , 47 9 64 0 , 25 0 87 7 , 44 9 Co l . l r i p 36 6 , 23 8 76 9 , 61 1 77 0 , 97 8 81 3 , 10 8 71 4 , 05 5 58 4 79 3 38 4 , 71 3 88 4 , 18 1 57 0 , 54 5 42 2 , 14 6 48 9 89 4 82 4 , 58 8 53 9 , 64 9 Ca l b o n 42 0 , 37 8 78 7 , 75 0 73 8 , 94 8 76 6 02 8 48 4 , 88 9 68 5 , 57 4 79 4 , 86 6 96 4 , 80 5 78 7 , 37 5 64 5 , 07 8 92 1 , 30 9 81 9 , 37 2 82 8 , 58 8 Na u g h l o n 82 , 96 0 , 59 7 02 8 , 58 3 64 9 , 28 3 21 8 19 1 50 5 , 17 3 40 6 34 4 83 7 , 06 4 08 1 , 36 3 74 1 , 32 9 16 6 , 39 3 50 8 , 86 4 72 7 46 3 09 2 , 54 5 Hu n l l n g l o n 43 1 , 89 5 89 7 , 84 8 08 2 , 43 0 17 9 , 44 2 58 8 27 4 88 0 , 38 2 52 5 , 00 8 78 8 , 80 8 59 1 , 54 2 71 5 , 87 2 80 3 , 18 7 41 7 , 37 3 40 3 , 7 4 5 Hu n ! e r 57 , 40 8 , 42 4 97 8 , 82 4 73 2 , 35 2 75 7 , 40 2 19 7 74 1 08 4 , 58 1 02 9 , 27 8 07 5 , 64 1 23 7 , 42 7 81 0 , 77 9 82 2 , 09 8 38 1 , 31 0 54 2 , 99 3 Blu n d e l l 88 0 , 71 1 31 4 , 04 9 30 0 , 65 2 30 3 , 81 8 30 9 , 7 3 8 30 3 , 15 1 30 5 , 24 4 31 0 , 48 0 31 0 , 23 4 29 5 , 08 9 29 9 , 34 0 30 3 , 88 7 30 5 , 03 2 Ch o l l a 35 , 49 5 , 46 4 37 5 , 11 1 85 0 80 9 82 2 , 30 3 53 8 , 82 3 44 7 , 70 0 50 2 , 88 9 51 4 , 23 5 18 2 , 88 8 55 4 , 34 7 75 7 , 13 8 81 5 , 18 8 55 3 , 85 8 Cra l 9 18 , 03 2 , 70 0 15 8 , 88 7 21 0 , 04 7 17 5 , 76 4 16 6 , 21 0 03 7 , 03 2 18 8 , 53 0 22 5 , 15 3 07 2 , 01 8 13 7 , 41 9 30 8 , 45 7 17 5 82 2 18 1 , 74 3 Ha y d e n 49 7 , 32 8 57 7 , 89 8 57 3 79 3 55 9 , 73 3 44 1 85 0 33 7 , 34 1 51 8 , 78 8 34 2 , 53 8 25 3 , 90 7 22 9 , 89 9 48 0 , 30 4 52 1 , 7 2 1 87 9 , 95 9 Ga d s b y 35 , 88 1 , 05 5 . 9 5 7 , 79 6 63 8 , 09 6 00 2 , 29 6 35 0 , 87 7 02 2 , 07 1 31 4 , 88 2 08 3 , 19 8 12 5 , 48 3 07 9 20 9 99 7 , 87 1 28 5 , 89 1 80 5 , 76 4 He r m l . l o n 58 1 , 53 7 78 0 , 34 0 43 3 , 48 5 92 9 , 96 8 17 7 , 80 0 45 8 , 94 1 47 9 , 67 4 37 2 , 98 1 58 7 , 81 8 51 3 , 51 8 48 9 , 83 7 49 5 , 81 1 90 1 , 74 8 Fo o t e C r o o k W i n d Ji m B r i d g e r F u e l C r o d t (1 7 05 9 88 9 ) (6 8 3 79 9 ) (1 , 95 9 , 79 6 ) (2 , 82 5 , 97 3 ) (1 , 88 8 , 49 9 ) (1 , 28 7 , 87 2 ) (2 , 10 2 , 30 7 ) (1 , 75 5 , 57 3 ) (2 , 70 9 , 35 2 ) (2 , 08 8 , 51 9 ) TO T A L F U E L B U R N E X P E N S E 48 7 31 5 , 98 5 47 , 53 8 , 71 2 43 , 93 1 , 42 8 48 , 98 8 , 11 5 37 , 40 9 , 48 2 32 , 89 8 08 9 38 , 48 4 , 81 2 41 , 97 4 , 94 7 40 , 74 1 , 78 5 87 0 , 54 2 41 , 18 7 , 80 3 70 7 , 19 1 41 , 79 4 , 09 0 -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - == = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - NE T P O W E R C O S T 83 2 , 73 7 , 08 8 37 , 27 9 , 42 9 33 , 33 5 , 24 1 34 , 31 5 , 17 7 29 , 25 8 , 81 3 38 , 89 4 , 88 8 77 , 27 5 , 85 1 11 1 , 91 0 , 43 4 10 0 , 85 2 , 38 5 82 , 77 8 , 82 2 58 , 79 2 , 53 8 83 , 13 7 , 22 7 18 8 , 50 2 == = = = = = = = = = = = = = = = = = = = = = = = = = = = -- - - - - - - - - - - - -- - - - - - - - - - - == = = = = = = = = = = == = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = -- - - - - - - - - - - - - - - - - - - - - - - - - == = = = = = = = = = = = -- - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - Ne t P o w e r C o s t I N e t S y s t e m L o a d 16 . 17 . 23 . 20 . 16 . 13 . 18 , 34 . Po w e r P I " , 20 1 2 0 0 2 Au . IR 1 , 14 J d . Pa c : l l l C o l p Ac t u l l l Ac l u s / 1 2 m o n l h s e n c f n g l 2 1 3 1 1 0 0 Ne t Co s t E n e r g y -y 8 1 8 (M W H ) 20 0 0 Je n Fe b Me r ArK Ma y J. . , Au g So p Oc t No v De e NE T S Y S T E M L D A D 53 , 39 3 35 1 68 7 , 32 4 28 7 , 27 2 27 4 , 03 8 94 0 , 52 1 21 4 58 3 47 8 , 83 4 83 4 , 79 9 83 8 , 05 7 17 2 , 92 1 29 7 , 29 1 80 9 , 30 4 78 0 , 80 9 SP E C I A L S A L E S F O R R E S A L E Bla c k H I l l I 50 5 , 88 9 42 , 70 6 39 , 24 8 43 , 34 4 41 , 48 3 41 , 53 8 98 5 42 , 80 0 42 , 35 1 42 , 02 2 42 , 58 8 41 , 97 0 87 8 So C I I I E d l l o n ( P ) 81 5 . 3 3 8 58 , 50 9 48 , 27 3 41 , 73 7 24 8 42 , 28 0 80 8 55 , 89 3 02 4 54 , 88 3 53 , 86 8 54 , 71 0 80 . 48 8 So C o l E d l l o n ( U ) 81 5 . 3 3 8 58 , 50 9 48 , 27 3 41 , 73 7 24 8 42 , 28 0 45 , 80 8 55 , 89 3 59 , 02 4 54 , 88 3 53 , 88 8 54 , 71 0 80 , 48 8 SM U D 39 1 . 72 3 81 , 08 8 51 , 58 5 23 , 74 0 (4 5 00 0 ) (1 0 40 1 ) (4 , 62 5 ) 38 5 65 , 07 0 70 , 59 2 65 , 20 5 48 , 15 0 13 , IP P S l l l e 53 2 91 9 75 1 42 , 48 7 48 1 41 , 41 8 43 , 95 0 41 7 48 , 84 1 48 , 98 7 48 , 91 1 49 , 09 4 45 , 23 2 43 , 39 0 PU l l e t P o w e r I I 05 1 , 20 0 10 4 , 10 0 44 0 00 0 68 , 50 0 82 , 72 5 65 , 30 0 90 , 42 5 99 , 20 0 91 , 52 5 91 , 00 0 82 , 51 0 88 , 47 5 SIe n a p a c l n c 21 8 , 38 3 55 , 38 2 52 , 33 5 55 , 78 0 52 , 80 7 SIe r r a P a d 1 I c I I 48 1 18 4 43 , 02 1 37 , 37 5 37 , 94 0 34 , 51 9 41 , 90 7 39 , 20 4 37 , 28 5 39 , 14 4 33 , 06 0 39 , 31 5 57 8 35 , 83 8 UM P A S a l e 99 8 51 3 14 2 32 7 99 2 08 4 49 9 85 8 55 8 78 0 94 0 29 1 23 4 CD W R S I l l s 81 3 , 03 3 50 , 05 3 80 0 53 , 59 0 49 , 72 1 88 8 20 0 49 , 80 0 50 , 00 0 48 , 05 3 49 , 80 0 54 , 28 4 57 , 48 4 WA P A S a I . 48 8 , 72 4 29 , 13 8 30 , 91 3 05 0 10 8 44 , 64 0 43 , 17 5 44 , 88 2 43 , 92 0 20 0 44 , 70 0 43 , 20 0 40 , 02 0 WA P A I I S o l e 55 5 28 4 55 , 80 8 52 , 19 9 42 , 78 4 47 , 4 0 0 38 , 80 0 31 , 20 0 57 , 00 0 55 , 80 0 00 0 55 , 87 5 00 0 12 , 90 0 PS C o S l l l e 15 7 , 45 8 98 , 23 8 91 , 78 4 17 2 98 , 48 2 10 0 , 59 9 98 , 90 0 98 , 88 4 98 , 83 2 88 , 35 1 10 0 , 93 0 97 , 53 8 97 , 08 8 EW E B S I l l s 9 5 23 8 , 4 0 5 35 , 00 0 34 , 70 0 37 , 05 0 22 , 93 0 35 , 55 0 38 , 00 0 37 , 17 5 Re d d i n g S o l e 33 7 , 38 0 35 , 20 5 52 0 29 , 25 8 25 , 20 0 28 , 07 4 28 , 89 2 38 , 80 0 38 , 20 0 38 , 95 0 28 , 07 5 25 , 40 8 CI a r 1 c S a l e 42 4 , 29 8 18 9 , 28 0 15 8 , 34 0 14 5 , 08 0 97 , 73 7 11 1 , 22 8 58 , 50 0 48 , 45 2 28 8 93 , 80 0 18 0 , 77 1 18 3 , 80 0 18 9 , 28 0 Hl n l o n 51 2 , 10 1 (8 1 4 ) 15 3 , 81 8 72 , 19 8 74 3 49 , 10 4 58 , 82 0 54 , 72 0 58 , 54 4 Bl a c k H I l l I C a p a c i t y S o l . 38 0 32 0 93 5 12 5 Bl a c k H I l l I S t o r & i J 8 52 5 01 5 83 5 87 5 Sp I I n g f t e i d 23 1 , 65 5 18 , 34 2 21 , 87 0 22 , 50 5 22 , 01 7 17 , 4 2 5 42 8 14 , 81 8 88 0 24 , 12 5 11 , 92 5 14 , 79 5 24 , 92 5 PN G C 37 1 , 98 5 40 , 92 0 38 , 28 0 40 , 92 0 31 , 4 6 5 64 0 43 , 20 0 44 , 70 0 43 , 20 0 44 , 64 0 Ch e y e n n e S a l e 97 1 . 2 4 2 71 1 77 , 20 4 81 , 77 0 77 , 22 4 79 , 96 5 78 , 12 3 43 5 84 , 25 4 85 9 78 , 79 3 83 , 05 9 88 , 04 5 De . . r e t S U p p l e m e n t a l 59 0 , 42 5 82 , 87 5 40 , 53 0 20 , 28 8 14 , 84 4 10 8 25 0 89 , 99 0 42 , 08 4 28 , 30 4 80 , 87 8 12 , 54 2 20 , 94 8 71 , 09 8 Ok a n 0 9 a n 89 2 85 5 94 2 24 1 45 2 38 1 18 0 72 0 27 4 88 8 59 9 32 0 08 0 UM P A I I S o l e 14 1 21 2 94 3 40 , 14 3 42 , 82 9 3~ , 82 2 88 7 (1 0 ) 79 8 Pla i n . E l e c t r i c G & T 23 7 , 24 1 34 , 98 8 28 , 29 2 78 0 45 , 82 0 47 , 73 7 44 , 84 8 Sp r i n g f i e l d I I 14 4 , 4 0 0 20 , 4 0 0 20 , 00 0 21 , 80 0 10 , 00 0 10 , 00 0 20 , 80 0 20 , 80 0 20 , 80 0 Co w t l l z - BH P 18 4 98 0 37 3 19 8 82 7 28 8 98 4 15 1 99 1 87 0 52 8 31 5 92 1 Cla r k - F W 93 8 88 9 38 8 71 8 34 8 59 8 41 5 8.7 0 0 98 8 93 2 Cla r k - 84 0 44 0 98 0 7. 4 4 0 19 0 44 0 20 0 44 0 44 0 20 0 45 0 20 0 44 0 Hu r r i c a n e S o l e . 65 2 41 2 40 8 44 7 48 8 80 1 70 4 78 1 1.4 5 8 09 4 50 8 31 1 88 4 AP P A - A E P C O 11 4 , 14 8 89 0 24 , 75 0 31 , 47 1 15 5 14 , 88 0 AP P A - E D # 2 38 , 97 8 99 8 19 5 82 1 75 8 71 8 70 0 03 7 75 3 AP P A - M e . a 41 , 98 4 64 0 32 0 08 4 64 0 32 0 Ci t i z e n . P o w e r 13 4 90 4 10 , 88 0 12 , 24 0 72 0 12 , 30 5 13 , 91 0 10 , 79 0 11 , 12 0 88 0 54 4 15 , 03 5 12 , 12 0 11 , 58 0 Gr e e n M o u n t a l n e 18 3 , 85 3 18 , 84 7 18 , 07 8 14 , 00 5 13 , 17 7 15 , 84 5 17 , 48 3 25 , 98 4 35 , 92 3 14 , 83 1 08 8 (1 , 42 2 ) 25 8 Aa l h e s d S i l l . 81 4 , 88 0 52 , 08 0 48 , 72 0 52 , 08 0 50 , 33 0 52 , 08 0 50 , 40 0 52 , 08 0 52 , 08 0 40 0 52 . 15 0 40 0 52 , 08 0 BP A W i n d S a l e 34 5 58 8 65 0 77 1 34 8 01 1 57 9 52 0 09 9 98 9 83 4 42 4 55 4 SD G & E S o l . 87 7 , 01 2 74 , 40 0 89 , 80 0 74 , 40 0 71 , 90 0 74 , 02 1 71 , 98 8 40 0 74 . 35 0 72 . 02 5 74 , 45 0 71 , 45 3 74 , 04 7 Sh o r t T e r m A r m S o l e I 14 , 08 2 . 42 9 95 7 , 58 7 94 4 , 37 0 28 2 , 75 4 02 9 , 49 7 93 8 , 94 7 10 1 , 52 1 77 8 , 15 8 07 8 78 4 21 3 51 1 89 0 99 4 88 8 , 00 8 22 4 , 34 0 Se c o n d a r y S a l e . 43 2 , 10 9 15 8 , 58 8 22 , 19 7 85 7 41 , 75 4 23 , 15 8 19 8 55 3 17 , 17 0 28 , 28 3 35 , 24 9 18 , 15 1 10 , 97 7 OT A L S P E C I A L S A L E S 29 , 28 2 , 59 8 53 3 , 18 0 38 9 , 25 0 57 9 , 90 5 18 1 , 25 8 16 8 , 84 5 21 3 , 87 2 88 4 , 58 5 31 1 , 75 8 45 0 , 58 0 98 2 , 77 9 09 1 , 04 4 43 5 , 78 2 -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - == = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = -- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - rO T A L R E Q U I R E M E N T S 82 , 85 5 94 7 22 0 , 50 4 65 8 , 52 2 65 3 , 94 1 10 1 , 77 9 38 3 , 42 8 89 2 , 30 8 79 9 , 38 4 14 7 , 81 3 82 3 , 50 1 28 0 , 07 0 70 0 , 34 8 21 8 , 37 1 == = = = = = = = = = = = = = = = = = = = = = = = = = = = == = = = = = = = = = = = -- - - - - - - - - - - -- - - - - - - - - - - == = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = -- - - - - - - - - - - -- - - - - - - - - - - PU R C H A S E D P O W E R & N E T I N T E R C H A N G E BP A S u p p l e m e n t a l C a p a c i t y Bl a c k H i l i . C a p a c i t y P u r c h a s . 58 4 78 1 29 4 35 5 88 8 21 2 Co G a n / J a m e s R i v e r 37 0 , 43 5 38 , 78 2 33 , 81 5 31 , 11 1 31 , 28 3 25 , 09 7 92 4 33 , 21 8 30 , 8 2 9 27 , 03 2 30 , 72 0 82 3 29 , 20 3 MId C o l u m b i a 21 0 88 9 25 9 , 70 3 19 4 , 41 8 19 1 , 08 1 23 9 , 86 8 19 8 37 4 18 4 , 29 9 15 8 18 7 14 1 , 4 1 1 14 9 , 04 7 13 5 , 01 0 16 8 , 40 3 18 4 , 93 2 Ca n a d i a n E n U U e m e n t (7 8 , 21 3 ) (8 , 4 1 1 ) (8 , 10 9 ) 58 8 ) (8 , 09 7 ) (8 , 50 2 ) (8 , 27 1 ) 33 4 ) 50 2 ) (8 , 27 7 ) (8 , 33 2 ) (8 , 32 0 ) (8 , 47 0 ) CS P E 84 , 78 1 09 8 57 5 68 3 39 5 81 7 40 4 78 5 76 5 40 4 82 8 40 4 76 5 Co l o c k u m (1 8 2 , 77 1 ) (2 0 , 84 5 ) (2 3 , 59 4 ) (1 9 , 88 8 ) 22 2 ) (3 , 11 9 ) 93 1 ) (4 , 84 8 ) (2 4 , 88 8 ) (1 8 , 0 3 8 ) (1 8 , 14 0 ) (1 9 , 44 8 ) (1 7 , 83 8 ) Gr a n t C o u n t y 87 . 80 0 39 4 99 0 81 8 7,4 0 9 34 2 99 8 27 8 55 9 09 8 90 0 72 8 09 0 PG E C o v e 24 , 08 4 02 8 93 2 02 8 97 8 02 8 98 0 08 4 02 8 98 0 03 0 98 0 02 8 US B R G r e e n . p r l n 9 . 82 0 50 4 45 4 59 4 52 8 15 2 55 7 02 0 10 1 97 8 93 4 IP C Re t u m (9 8 , 44 1 ) (5 , 79 9 ) (9 , 47 7 ) (8 , 35 2 ) (7 , 93 5 ) (1 1 , 01 5 ) (1 1 , 14 4 ) (9 , 16 8 ) (5 , 27 2 ) 03 7 ) 14 8 ) (7 , 99 8 ) (1 0 , 09 8 ) F. C o n t r a c t s - P P & L 49 8 , 12 9 47 , 22 3 52 , 65 9 39 , 07 8 39 , 88 3 39 , 01 2 34 , 88 8 87 0 19 3 89 4 81 0 33 , 41 7 70 4 Tr l S l a t e P u r c h a s e 28 4 , 95 5 32 , 08 7 31 , 81 8 83 9 35 3 55 0 22 , 37 9 21 , 38 3 73 8 18 , 4 0 2 13 , 4 2 0 15 , 84 8 15 , 38 0 So u t h I d a h o E x c h a n g e 84 2 (4 ) (1 , 20 3 ) 38 0 ) 89 0 10 , 65 3 88 9 58 3 (5 4 3 ) 28 3 (7 , 40 4 ) AP S P u r c h a s e 48 8 17 8 1,4 0 0 15 0 45 3 (5 , 15 3 ) 77 5 74 , 80 5 19 , 00 0 11 1 , 70 0 22 8 , 39 8 28 , 85 0 Tr I S i a l . E x c h a n g e 20 2 , 93 8 08 2 03 7 31 1 18 , 25 0 20 , 00 0 80 0 24 , 39 0 28 , 04 0 25 , 09 1 24 , 78 8 23 , 94 3 20 4 Po w e r P I a 20 1 2 0 0 2 At t JR 1 . 14 . xI . SC E P u r c h a s e 18 4 , 82 0 89 0 15 , 30 4 98 , 89 8 47 , 73 0 BP A E x c h e n g e (2 0 3 , 27 5 ) (5 0 , 00 0 ) (2 8 , 00 0 ) (8 0 0 ) (4 1 , 67 5 ) (4 1 40 0 ) (4 1 , 40 0 ) Av t s l B S I I I m 8 r P u r c h a s e 82 , 80 0 98 8 20 , 98 8 32 , 03 9 12 , 62 1 18 4 Av t s l B E x c h e n g e (4 1 47 5 ) (9 , 00 0 ) (8 , 95 0 ) (6 , 15 0 ) (1 1 , 45 0 ) (4 , 40 0 ) (1 , 52 5 ) Ge m S l a t e 54 , 88 8 14 , 75 1 15 , 28 1 14 , 33 3 10 , 54 3 GS L M 91 5 71 0 89 8 74 9 49 1 20 8 48 8 57 2 QF C o n l r a c t s - U P & L 49 7 , 19 3 42 , 44 9 75 0 45 , 83 0 33 , 34 7 75 3 16 1 51 7 40 4 63 7 42 , 90 8 42 , 88 1 43 , 74 8 IP P P u r c h a s e 53 2 , 91 9 75 1 42 , 46 7 24 , 48 1 41 , 41 8 43 , 95 0 47 , 41 7 48 , 84 1 48 , 98 7 48 , 91 1 49 , 09 4 45 , 23 2 43 , 39 0 Bla c k H i l l s S U p l u s 18 7 , 95 5 70 0 15 0 02 0 15 , 39 5 10 , 49 5 19 , 14 5 69 5 30 , 53 0 29 , 07 5 12 , 97 0 08 0 22 , 70 0 Re d d i n g P u r c h a s e 14 0 . 0 2 5 13 , 12 2 81 4 12 , 54 4 10 , 17 5 11 , 20 2 15 , 24 7 15 , 49 9 15 , 83 2 11 , 91 0 12 , 87 6 12 , 80 4 He r n i s l o n P u r c h a s e 94 0 , 77 0 17 8 53 3 15 6 , 28 8 13 1 , 40 0 15 1 , 96 1 14 9 , 7 2 2 16 2 , 10 1 1 18 8 79 7 18 8 67 0 18 5 20 0 18 8 , 25 7 15 9 , 10 0 17 9 , 75 5 De s e r e t E x p a n s i o n 20 2 , 07 0 19 , 53 5 15 , 02 8 13 , 10 3 18 , 49 6 18 , 77 5 67 7 15 , 84 2 19 , 21 3 18 , 24 3 16 , 23 6 13 , 20 2 18 , 91 8 De s e r e t R e s . . . . C 8 P u r c h a s e 37 2 , 40 1 25 , 84 5 88 , 19 9 71 , 51 0 83 , 63 7 24 , 42 4 48 , 75 1 13 , 60 5 15 , 53 0 27 0 53 , 97 1 32 , 17 2 (8 8 , 31 3 ) AP S E x c h a n g e (8 2 5 ) 14 2 , 84 8 69 , 12 0 (7 8 33 6 ) (1 3 6 24 0 ) (1 4 2 , 81 5 ) (3 6 , 45 3 ) (2 5 0 ) 78 , 33 8 (3 7 , 01 1 2 ) 14 2 , 05 7 Hu r r i c a n e P u r c h a s e 89 9 10 8 12 9 13 1 10 0 Fo o l e C r e e K Re d d i n g E x c h a n g e 11 , 17 7 11 , 17 7 Tra n s A l l B P u r c h a s e 30 8 , 99 6 22 3 , 20 0 22 3 , 20 0 21 2 , 79 2 22 2 , 97 5 21 2 , 25 0 21 4 , 57 9 Fo o t e C r e e K I V P u r c h 82 1 82 1 Sh o r t T e n n A n n P u r c h a s e s 17 , 11 9 , 65 7 92 8 , 73 6 96 3 , 37 5 1. 0 8 8 , 18 4 73 9 , 05 5 37 1 , 55 9 78 4 , 35 4 47 3 , 06 9 72 9 , 55 5 47 2 , 53 4 67 0 , 81 5 11 7 , 62 6 78 2 , 78 3 Se c o n d a r y P u r c h a s e s 86 7 , 59 7 24 8 , 3 3 9 15 1 , 09 8 16 9 , 24 5 28 8 84 7 23 0 , 88 3 23 8 , 23 7 17 8 , 68 2 28 , 92 2 51 , 48 4 85 , 01 8 14 0 , 80 3 80 , 28 9 TO T A L P U R C H A S E D P W & N E T I N T . 26 , 20 6 , 69 6 02 2 , 64 1 63 5 , 15 3 80 5 , 33 4 88 5 . 75 7 18 5 , 66 2 54 1 , 56 2 34 0 , 72 6 64 3 . 91 7 32 4 , 71 3 73 2 , 76 3 26 3 , 43 9 61 5 , 00 9 CO A L A R E D G E N E R A T I O N Ce n l r a l l a 53 2 . 88 4 43 2 , 95 4 36 9 , 70 7 44 8 , 91 5 24 7 , 33 4 13 , 97 4 Da v e J o h n s t o n 66 7 26 7 45 7 , 91 0 44 1 , 67 3 44 1 , 68 0 42 8 35 8 48 4 , 52 1 43 9 , 08 7 43 1 , 07 8 43 8 , 61 1 51 5 , 12 5 50 0 15 8 52 9 , 68 2 55 1 , 42 6 Jim B r i d g e r 10 , 77 8 24 7 95 6 , 42 5 84 7 , 37 7 00 3 58 8 82 0 , 77 4 75 3 93 9 75 4 82 0 89 5 , 85 4 84 3 , 21 3 &8 2 21 8 97 6 , 08 4 95 3 , 20 0 98 6 75 5 Wy o d a k 13 5 , 03 8 19 7 , 63 0 18 9 51 4 20 3 , 83 9 19 5 , 17 4 23 , 34 8 11 9 , 81 1 20 0 , 70 9 20 1 59 2 19 8 , 00 3 20 0 , 71 2 20 1 , 87 3 20 2 , 83 3 Co l s l r 1 p 98 8 , 47 9 84 , 84 4 95 , 42 9 10 7 , 84 3 74 0 58 , 72 3 48 , 62 8 74 , 00 4 28 7 53 , 72 8 71 , 84 0 10 2 , 60 4 21 1 Ca r b o n 37 2 , 23 8 12 2 , 4 8 0 11 9 32 6 11 4 , 18 0 75 , 82 6 10 1 , 61 6 11 4 , 00 4 12 5 , 11 9 11 8 , 89 8 12 1 , 79 1 12 2 , 21 7 11 7 , 92 2 11 8 85 7 N~ l o n 36 6 , 41 0 47 2 , 16 2 43 1 , 10 3 46 7 , 14 1 42 0 , 17 6 45 8 , 58 4 39 3 91 3 44 0 88 2 45 8 , 75 8 45 8 , 83 7 46 7 , 33 9 43 1 , 05 4 47 2 , 84 1 Hu n H n g l o n 05 3 , 19 5 80 5 , 76 0 51 4 48 7 52 0 , 13 3 56 8 , 99 1 84 4 , 60 3 55 8 , 48 8 61 8 32 3 60 4 , 17 8 58 7 57 3 61 6 , 23 4 58 3 , 20 1 61 1 , 04 4 Hu n t e r 07 0 , 63 0 71 1 70 2 68 0 18 7 88 8 51 2 75 7 , 16 6 75 4 , 50 6 70 3 , 4 7 6 72 5 , 88 5 72 9 , 93 3 85 2 , 11 4 63 9 , 77 9 57 5 , 69 7 45 1 , 87 3 Bl u n d e l l 15 1 , 73 8 13 , 71 8 12 , 85 7 12 , 79 1 13 , 39 0 12 , 82 1 12 , 53 8 12 , 91 9 12 , 93 9 10 , 88 8 11 , 59 7 12 , 35 3 13 , 14 7 Ch o l l a 32 2 , 60 1 20 2 , 71 2 22 9 , 07 2 22 4 , 13 8 34 , 20 3 82 , 27 8 17 3 , 15 2 25 5 , 85 2 22 7 , 48 9 18 8 , 10 0 23 6 , 88 9 23 8 , 08 0 23 0 , 8 3 8 Cr a i g 38 4 , 95 9 11 4 , 4 2 4 11 3 15 1 12 1 , 88 5 10 0 36 0 91 , 99 3 11 5 , 59 1 12 0 , 00 1 11 7 , 48 5 11 8 , 32 0 11 7 , 41 3 11 7 58 3 11 8 , 97 3 Ha y d e n 51 3 , 14 5 55 , 83 2 24 1 53 , 40 4 37 , 40 3 13 9 53 , 83 4 31 , 48 4 24 , 27 6 22 , 43 1 42 , 60 1 02 5 57 , 4 7 5 Ga d s b y 71 8 , 12 0 24 , 84 0 23 , 75 5 85 0 32 , 58 8 45 , 45 8 16 9 85 , 53 4 97 , 33 6 88 , 83 9 71 , 04 7 67 , 90 0 79 , 02 4 He m i s t o n 84 1 53 7 17 9 , 85 9 15 7 , 45 2 13 1 40 7 15 1 , 96 0 14 9 , 72 4 18 2 , 09 9 18 6 , 80 1 1 18 8 , 78 8 18 5 , 17 9 18 8 , 41 0 15 9 , 12 3 17 9 , 72 9 Fo o t e C r e e k W i n d 11 1 22 6 14 , 67 7 12 , 73 9 90 7 78 8 90 9 77 6 99 2 51 1 78 8 92 1 11 , 61 9 14 , 58 8 Pa c i f i c W e . 1 W i n d 50 9 39 0 52 4 59 5 Tro j a n (5 1 9 ) (5 6 ) (5 2 ) (5 1 ) (5 3 ) (4 1 ) (3 6 ) (3 7 ) (3 5 ) (3 3 ) (3 4 ) (4 3 ) (4 6 ) TO T A L C O A L F I R E D G E N E R A T I O N 50 , 06 6 , 68 f 66 0 , 26 3 31 0 , 34 2 57 6 , 11 5 99 9 , 16 0 72 3 , 29 3 75 1 , 32 6 16 7 , 60 6 24 1 , 25 5 04 8 , 68 2 25 0 , 00 5 15 2 , 85 3 16 7 , 36 6 TO T A L S Y S T E M H Y D R O 36 0 , 55 4 53 7 , 56 0 51 1 , 02 7 47 0 , 49 2 40 6 , 66 2 41 1 4 , 45 3 39 9 , 41 6 27 0 63 0 26 2 , 64 2 25 1 , 69 6 27 7 . 30 2 26 4 , 05 6 21 3 , 99 6 =- ~ TO T A L R E S O U R C E S 85 5 , 11 4 6 22 0 , 50 4 65 6 , 52 2 85 3 . 11 4 1 10 1 , 77 9 38 3 . 42 8 69 2 , 30 8 79 9 , 3 6 4 14 7 . 81 4 82 3 , 50 1 28 0 , 07 0 70 0 , 34 8 21 6 , 37 1 == = = = = = = = = = = = = = = = = = = = = = = = = = = = -- - - - - - - - - - - - == = = = = = = = = = = == = = = = = = = = = = == = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = == = = = = = = = = = = = == = = = = = = = = = = = = = = = = = = = = = = = = == = = = = = = = = = = = = = = = = = = = = = = = -- - - - - - - - - - - - Po w e r P i a 20 1 2 0 0 2 Atb JR 1 . 1 4 . xI . Pa d f l C o t p Ac / u s l 1 2 m o n / h s e n d i n g 1 2 / 3 1 1 0 1 No ' Po - Co I ' A n 8 l , I 1 8 (S ) 20 0 1 JS 1 Fo b MO l ' Ma , Ju n Ju l Au g So p Oc t No y De e SP E C I A L S A L E S F O R R E S A L E Bl o c k H i l l i 91 9 . 59 3 19 0 70 9 04 0 , 02 5 13 3 , 03 9 11 9 91 2 13 4 , 46 0 12 4 . 82 7 18 1 , 73 2 25 5 , 38 2 18 5 , 90 8 19 9 , 38 1 18 9 . 24 8 18 5 . 21 2 So C a I E d l l o n ( P ) 46 . 02 2 . 58 5 4, 4 0 8 . 23 3 81 8 09 1 82 1 . 95 3 74 6 . 01 5 75 5 , 50 0 79 8 51 5 24 9 , 19 2 29 8 , 32 5 58 3 , 04 8 54 8 . 25 1 45 8 38 0 53 8 . 08 4 So C I I I E d l l o n ( U ) 46 . 02 2 . 58 5 40 8 23 3 81 8 . 09 1 82 1 . 95 3 74 6 . 01 5 75 5 . 50 0 79 8 , 51 5 24 9 , 19 2 29 8 , 32 5 58 3 , 04 8 54 8 , 25 1 45 8 , 38 0 53 9 , 0 8 4 SM U D 13 4 , 58 0 08 2 , 87 4 43 2 , 89 2 33 5 , 23 9 34 8 , 30 2 33 7 , 0 2 1 43 8 , 0 7 0 42 2 , 15 5 80 4 , 94 4 41 9 , 88 4 12 5 , 17 1 37 8 88 4 03 5 , 18 4 IP P S o i o 22 . 78 4 , 87 3 08 8 , 28 9 08 3 , 88 1 00 9 , 29 1 01 9 . 31 1 11 2 , 93 1 93 7 , 19 9 00 8 . 89 7 99 3 . 03 2 41 9 , 4 2 3 04 4 , 05 5 07 0 . 78 4 Pu g e t P o w e r I I 50 , 24 2 , 4 0 3 4,4 0 2 , 92 8 84 9 , 18 5 75 8 , 51 2 84 2 , 34 3 05 5 , 38 9 77 4 , 21 3 40 0 , 25 1 4, 4 5 7 , 05 3 38 0 , 79 9 45 7 , 05 3 38 4 , 88 2 48 1 , 83 5 Sio r r o P o o i f t c (5 8 5 , 88 2 ) (5 8 5 . 88 2 ) 51 0 " 0 P o c I 1 I c I I 23 . 54 7 94 1 04 1 . 54 8 90 5 38 0 01 7 27 9 92 9 81 1 82 8 . 97 4 87 3 52 7 18 5 . 18 1 17 2 . 93 2 09 0 , 81 5 98 8 . 54 1 38 3 , 4 0 0 39 2 . 75 5 UM P A S o I o 55 1 28 2 21 7 , 43 1 20 8 . 25 2 21 4 , 77 2 21 5 , 84 9 20 7 , 11 3 21 1 , 94 5 22 0 . 80 3 21 8 , 97 5 21 2 , 80 3 21 1 , 77 1 19 5 , 89 1 21 7 , 87 7 CD W R S o l o 33 . 84 1 , 32 3 94 1 , 08 4 72 5 , 44 4 74 7 39 5 75 5 . 02 3 82 4 , 98 8 72 2 , 88 4 85 8 , 99 5 01 0 . 45 0 93 0 , 05 2 3,0 3 5 , 13 8 94 9 , 51 2 14 0 82 0 WA P A S o I o 35 8 . 98 0 28 1 , 82 4 13 9 , 71 2 18 8 . 17 8 ) (1 , 78 0 , 57 8 ) (3 7 8 17 8 ) 78 9 12 0 28 1 . 82 4 28 1 82 4 22 1 , 12 0 28 3 , 52 0 22 1 . 12 0 26 1 82 4 PS C o S o l o 53 , 13 0 . 85 8 57 5 38 9 37 1 , 19 0 84 4 , 91 8 50 9 , 82 1 58 2 , 12 8 55 7 88 2 84 3 . 94 5 89 3 28 9 55 8 , 01 5 84 8 91 7 54 8 19 5 82 1 , 20 9 Ro d d l n g S o l o (8 1 2 . 24 5 ) (8 1 2 , 24 5 ) Cle r k S o l o 18 , 39 8 , 54 0 33 7 . 00 3 03 3 , 80 9 71 7 , 43 1 33 1 , 09 4 18 2 , 82 1 01 4 27 9 78 2 , 30 3 Cle r k 5 & 1 S o l o 83 0 . 85 3 28 8 , 4 8 0 (7 8 , 88 5 ) 84 , 24 8 33 4 , 83 2 Hi n s o n 14 7 , 28 8 14 7 , 28 8 Blo c k H i l l i C a p o c l t y 51 1 1 0 91 8 . 30 5 34 1 38 3 08 9 59 8 22 7 , 14 4 29 4 , 88 0 38 3 , 09 0 Sp r l n g t l o l d 15 1 , 4 8 2 28 2 . 88 8 32 2 , 54 3 05 8 13 1 35 8 15 8 22 9 , 74 6 18 3 , 47 5 58 2 , 22 8 87 7 70 4 77 0 82 8 73 8 , 50 1 97 0 , 81 4 82 2 . 88 8 PN G C 95 8 74 1 78 1 . 58 3 89 5 . 78 1 . 58 3 73 8 49 3 Ch o y o M O S o l o 99 8 28 8 20 5 , 51 7 89 0 , 33 4 (9 7 58 3 ) Do s e r o t S u p p i o m o n t o J 19 . 84 8 , 19 8 89 7 , 18 7 78 9 28 3 85 5 45 5 (8 0 2 , 98 1 ) 07 0 00 0 59 3 , 88 5 98 3 . 84 1 83 5 . 00 0 30 0 39 5 40 0 . 00 0 18 7 93 5 59 8 , 4 5 8 Do s o r o ' D l l p l a c o r n o n t 19 8 , 73 0 82 3 23 . 01 0 19 , 88 3 28 . 3 2 8 85 , 51 5 12 , 21 8 93 0 Ok S 1 0 g o n 44 5 . 98 1 78 . 40 8 85 , 95 7 57 . 30 5 45 , 80 2 29 , 21 9 09 3 47 . 18 8 44 . 93 8 53 . 27 3 UM P A I I S o l o 82 9 88 8 89 , 85 2 24 7 , 95 2 58 3 . 54 8 88 8 , 32 0 93 7 , 78 4 88 9 . 29 8 88 , 97 8 43 , 4 5 2 30 0 , 90 8 Sp r i n g t I o l d I I 18 . 83 0 39 7 32 3 35 8 , 87 2 39 7 32 3 19 5 , 28 2 21 0 30 2 (4 4 7 . 93 8 ) (4 3 5 . 98 8 ) (8 5 8 . 58 8 ) Co w l i l z - B H P 23 5 . 19 1 10 2 . 52 3 10 2 , 52 3 51 7 97 , 14 2 10 0 , 25 1 10 2 , 19 3 10 3 33 8 11 4 35 1 10 8 07 4 10 9 , 18 4 99 . 47 0 84 5 Cl e r k - W T 42 8 , 4 8 0 12 1 . 11 2 11 0 , 4 5 8 12 1 , 11 2 11 7 , 41 2 12 1 . 11 2 11 7 , 58 0 12 1 , 11 2 12 1 , 11 2 11 7 . 58 0 12 1 , 28 0 11 7 , 58 0 12 1 11 2 Hu r r t c o n o S o l o s 28 9 83 2 31 , 50 0 50 0 88 4 83 8 94 0 25 . 58 4 72 0 28 , 84 4 15 8 17 , 10 8 AP P A - AE P C O 94 5 , 0 7 4 90 5 38 1 90 5 38 1 13 4 31 2 Clt l z o n s P o w e r 02 7 . 92 5 43 3 , 29 8 38 7 02 7 11 2 , 4 0 2 42 5 01 0 39 0 , 15 3 41 8 . 4 8 4 39 9 20 8 20 3 , 80 7 99 , 89 0 48 8 , 17 0 44 5 , 72 1 24 6 . 97 7 Gr o o n M o u n t a i n s 88 4 . 70 5 88 9 80 2 13 7 92 8 (3 . 84 2 01 3 ) (1 7 3 , 82 6 ) 72 , 81 4 Flo t h o o d S o l o 15 . 97 0 58 0 24 2 , 10 8 12 1 , 90 4 24 2 , 10 8 20 0 , 37 0 24 2 . 10 8 20 2 . 04 0 38 9 , 84 0 38 9 , 84 0 29 3 , 20 0 54 2 , 38 0 57 8 , 78 5 58 8 , 33 7 BP A W i n d S o l o 98 8 , 47 0 32 8 , 55 8 30 0 . 87 0 28 2 . 97 8 24 4 , 17 3 27 0 , 28 7 20 4 , 22 3 13 8 , 79 8 85 . 58 7 18 2 , 79 3 39 3 . 54 4 19 1 . 37 9 38 7 , 30 0 SD G & E S o l o 14 , 4 0 8 . 39 0 22 2 71 2 10 5 , 19 3 22 3 88 0 18 2 , 75 5 22 3 , 48 5 18 4 , 4 0 0 22 3 , 88 0 22 3 , 88 0 1. 1 8 4 , 40 0 22 5 52 5 18 4 , 40 0 22 3 , 88 0 BP A - A a t h o o d S o l o 5,4 2 7 . 51 3 83 0 , 48 5 78 9 , 04 0 82 8 , 00 8 Sh o r l T e r m F I n n S o l o s 59 8 , 73 9 . 93 3 11 8 , 24 8 73 9 14 3 01 2 87 0 18 5 , 14 0 52 3 25 9 . 85 2 . 37 5 17 8 50 6 . 72 7 12 0 94 8 . 4 1 9 14 6 , 47 2 , 57 2 15 3 . 38 4 09 1 17 4 , 4 8 0 , 4 8 1 49 . 41 0 15 1 52 . 31 3 . 47 1 01 3 , 51 4 So c o n d a r y S a l o s 74 8 . 38 0 78 8 18 9 82 2 85 0 8, 4 7 8 87 0 88 8 19 9 4,4 2 3 71 4 75 5 , 38 3 59 1 , 41 4 54 8 , 83 5 88 1 21 1 79 2 . 35 8 41 9 . 27 2 82 2 , 50 5 TO T A L S P E C I A L S A L E S 03 4 58 7 , 38 4 18 9 , 88 4 , 15 1 18 5 , 83 8 30 7 21 0 , 04 9 , 24 7 29 1 , 18 8 38 1 21 2 , 21 3 19 0 15 2 20 4 , 04 2 18 1 , 28 8 , 92 9 19 0 , 38 9 , 48 4 20 5 , 50 2 55 1 82 , 44 1 , 41 9 84 , 71 9 81 3 81 1 , 24 1 , 11 9 0 PU R C H A S E D P O W E R & N E T I N T E R C H A N G E BP A P o a k l n g P u r c h a o e 29 9 . 75 0 18 0 . 00 0 18 0 00 0 18 0 00 0 18 0 . 00 0 18 0 00 0 18 0 , 00 0 18 0 . 00 0 18 0 . 00 0 18 0 , 00 0 89 3 25 0 89 3 , 25 0 89 3 25 0 BP A E n a a o m o n t C a p a c i t y 25 , 8 3 8 17 7 17 7 17 7 14 5 14 5 14 5 14 5 14 5 14 5 14 5 14 5 14 5 BP A S U p p i o m o n t a i C a p o c l t y 83 8 17 7 17 7 17 7 14 5 14 5 14 5 14 5 14 5 14 5 14 5 14 5 14 5 Bla c k H i l l s C a p a c i t y P u r c h a s o 39 2 98 8 17 5 , 02 3 13 2 . 18 1 11 8 50 1 12 0 55 8 10 6 28 4 11 3 , 98 9 13 8 27 4 11 0 57 3 88 2 58 2 13 8 87 8 72 5 Co G a n / J a m e s R i v e r 15 , 38 8 91 4 38 8 , 24 8 29 4 , 91 7 35 9 . 57 7 40 1 23 5 28 8 79 9 41 0 , 51 7 53 4 . 53 9 33 4 , 90 0 27 8 , 0 8 1 1. 0 9 8 28 8 93 3 , 08 5 07 8 . 75 1 Do u g P U D S e l l l o m o n t 58 0 , 34 9 94 . 18 3 38 3 33 0 00 9 50 1 84 , 19 1 33 1 45 . 88 7 58 , 83 2 41 . 31 0 55 . 85 3 (1 0 0 . 04 1 ) MId C o l u m b i a 18 . 11 8 , 73 1 18 2 . 14 4 25 3 . 11 5 34 8 , 88 9 14 1 . 08 3 25 4 . 85 5 28 2 80 9 21 4 . 01 2 22 5 , 87 3 23 4 . 84 4 1. 2 7 1 . 41 0 25 4 44 0 49 7 , 85 7 Gr a n t C o u n t y 59 3 . 08 5 22 3 . 79 0 17 4 . 85 0 20 3 83 0 25 9 31 5 32 8 97 0 34 9 . 88 0 35 9 73 0 33 4 58 5 24 8 38 0 20 6 . 50 0 48 9 . 83 1 43 5 88 4 US S R G t o o n s p r l n g s 29 8 15 , 29 8 PG E C o v e 22 2 . 30 2 18 . 98 1 18 . 98 1 18 . 98 1 98 1 88 9 17 , 84 0 11 , 14 4 98 1 18 . 98 1 18 , 98 1 18 . 98 1 18 , 98 1 F, C o n l J a c l s - P P & L 84 , 83 1 . 02 8 28 2 31 9 98 8 , 24 9 89 2 . 42 5 90 8 , 4 2 0 82 0 . 99 0 90 8 15 7 88 1 , 49 7 89 8 . 95 4 37 5 , 46 1 30 9 , 89 5 20 0 . 00 8 58 8 , 85 3 Tri S t a t e P U ' c h a s e 10 , 37 0 , 72 4 83 0 , 50 9 77 2 . 49 0 78 2 , 84 5 35 3 , 87 4 27 2 , 72 9 85 2 , 32 2 91 3 , 78 8 90 1 , 84 1 88 3 , 72 7 91 0 , 45 2 93 2 , 78 7 98 4 . 00 0 So u t h I d a h o Sto r a g e (1 0 , 24 0 ) (1 0 . 24 0 ) (1 8 0 ) 18 0 AP S P u r c h a o e 18 . 28 5 . 15 7 89 4 , 13 7 48 8 . 17 3 70 9 38 8 84 0 11 3 05 3 18 9 (1 3 9 , 77 1 ) 78 5 44 , 55 4 18 , 0 7 8 (7 1 8 ) 14 7 , 23 8 37 8 , 0 1 1 Tr i S t a t e E x c h o n g o SC E P u r c h a s o 85 0 17 2 88 8 . 90 0 88 8 90 0 00 0 , 00 0 (1 . 18 8 . 55 0 ) 13 0 81 8 03 7 , 59 3 21 5 , 49 8 (5 , f I 9 0 ) 30 5 . 20 3 Av l s t a S u m m e r P U ' c h a s o 12 , 04 4 . 81 9 44 7 . 21 8 41 7 30 8 93 2 , 08 4 24 8 01 1 Av l s t a E x c h o n g e Ge m S t e l e 10 0 . 72 1 20 7 , 4 0 0 21 1 , 90 0 20 7 , 4 0 0 20 7 , 40 0 20 7 , 40 0 20 7 , 4 0 0 20 7 40 0 5. 3 0 0 20 7 . 40 0 20 7 , 4 0 0 19 , 22 1 20 5 . 10 0 GS L M 3,4 2 5 . 85 4 23 5 89 5 15 8 . 82 9 88 8 . 17 9 78 4 , 81 8 29 0 , 89 9 89 , 83 4 QF C o n l J a c l s - U P & L 58 . 73 0 15 4 19 9 . 98 9 83 8 , 83 7 83 8 . 70 1 97 7 , 89 9 49 8 , 05 3 4,4 0 3 , 50 1 00 8 . 87 1 5,4 1 1 88 8 45 0 , 80 2 22 2 . 11 9 22 3 , 88 8 85 8 , 04 8 IP P P u ' c h B g e 22 . 78 4 . 87 3 08 8 . 28 9 08 3 , 88 1 00 9 29 1 01 9 , 31 1 11 2 , 93 1 93 7 19 9 00 8 , 89 7 99 3 03 2 41 9 , 4 2 3 04 4 . 05 5 07 0 . 78 4 Bla c k H i l l s S u r p l u s He n n l s t o n P u r c h a s e 77 . 08 7 , 88 7 80 8 , 99 2 38 0 , 87 5 30 9 , 88 8 50 8 , 97 3 05 0 . 34 8 17 8 , 88 5 30 0 , 00 0 77 0 . 11 0 38 0 23 5 42 6 . 79 2 42 4 47 5 77 2 , 33 4 De s e r e t E x p o n s l o n 87 0 22 7 28 1 14 3 , 87 4 14 3 . 82 3 35 7 58 4 15 4 , 83 5 10 9 02 8 17 4 , 79 7 11 8 . 80 4 10 8 , 10 0 12 2 , 82 4 18 4 . 00 0 70 1 ) Po w e r P i o n . ;0 / 2 0 0 2 Al i a R1 . 14 . De s e , e t R e s . . . . c e P u r " " . . e 12 , 88 8 , 75 9 32 2 , 18 2 54 8 , 0 1 4 74 1 , 25 4 41 3 , 02 3 93 5 , 00 0 (9 8 1 , 87 2 ) 48 5 , 87 2 43 9 , 00 0 20 8 . 09 3 88 5 00 0 30 0 . 27 4 (1 8 8 , 88 1 ) HL l T i c a n e P u r c h . . e 35 , 80 8 26 6 99 9 57 7 93 5 52 7 94 5 82 6 26 8 34 1 47 1 59 6 63 5 LT F R e s e r v e P u r c h . . e e 01 9 , 55 3 32 1 . 50 0 20 1 47 2 31 9 19 5 32 0 88 9 31 9 , 38 0 31 9 11 8 26 4 , 98 7 19 5 59 9 20 9 50 0 20 9 , 50 0 18 9 , 33 8 16 9 33 5 Tre n o A J l a P u r c h a s e 77 . 74 2 , 38 0 50 8 06 4 91 6 , 05 0 45 7 , 71 2 46 0 , 31 7 83 8 , 19 4 41 9 . 27 6 28 6 93 9 14 0 , 18 3 62 2 , 67 1 26 4 , 90 0 30 6 . 04 4 34 3 , 62 0 Fo o t e C r e e k I V P u r c : h l E x c h e n g e 24 7 19 0 75 , 21 4 10 0 90 6 32 , 16 2 25 , 94 3 17 . 47 5 71 2 18 , 87 2 30 3 18 0 32 3 DS M ( L o e d C u r t a i l m e n t ) 93 0 . 61 2 (4 1 , 73 4 ) 77 5 46 0 (1 , 29 2 , 17 6 ) 71 9 . 95 5 61 6 , 32 0 07 7 , 56 6 15 , 91 4 , 44 1 60 9 , 25 2 95 7 , 33 2 37 0 , 76 4 78 2 , 59 7 39 , 03 7 20 1 2 0 Cu s t o m e r C h e l l o n g e 31 , 86 4 , 65 6 36 , 33 6 65 9 , 08 6 14 7 , 94 2 15 , 96 3 , 02 0 71 7 , 59 5 99 9 , 99 9 30 1 , 69 1 46 . 98 6 En r o l l P u r c h . . e 69 7 , 60 0 43 1 , 60 0 39 8 , 40 0 44 8 , 20 0 43 1 , 60 0 43 1 , 80 0 43 1 , 60 0 43 1 , 60 0 44 6 , 20 0 39 8 , 40 0 44 6 20 0 39 6 , 40 0 Aq u l l e H y ! t o H e d g e 43 7 , 50 3 14 5 . 83 7 14 5 , 83 3 14 5 , 83 3 Ga d s b y P e e k e " , 35 . 44 2 , 76 5 46 2 . 60 0 06 3 . 51 0 63 6 . 97 4 38 3 , 45 6 97 9 , 82 9 78 8 . 41 7 37 3 , 15 2 55 4 , 62 6 Sh o r t T e r m R r m P u r c h a s e s 92 9 . 01 9 , 65 8 17 2 , 62 1 , 92 3 16 6 , 53 3 , 38 2 14 2 , 00 8 56 8 29 2 , 58 8 25 0 16 9 90 4 , 96 5 15 4 , 24 5 . 92 8 25 8 , 85 7 , 17 5 24 0 . 47 0 34 4 21 4 53 8 , 92 8 37 , 30 7 , 05 2 41 , 30 6 , 89 4 83 6 , 42 8 Se c o n d a r y P u r c h a s e s 12 8 , 62 6 , 09 5 24 , 04 7 , 64 7 15 , 00 6 44 7 16 , 59 0 , 99 5 13 , 32 1 31 5 21 7 , 97 2 64 8 . 41 6 99 9 , 79 9 16 3 . 54 2 (1 . 41 9 , 87 1 ) 59 2 . 61 3 52 3 , 67 2 93 3 , 54 8 TO T A L P U R C H A S E D P W & N E T I N T . 64 4 , 57 3 , 04 0 23 6 , 36 8 , 84 0 22 9 . 30 4 , 78 7 19 8 . 99 0 22 4 34 7 , 24 1 , 84 3 24 2 , 58 8 , 31 8 21 8 , 27 1 , 94 2 33 7 , 75 3 , 88 8 32 3 , 37 7 , 74 2 28 7 , 17 9 55 4 81 , 23 1 , 31 2 80 , 52 8 , 71 7 81 , 74 2 , 07 5 TO T A L W H E E U N G & U . O F F . E X P E N S E 11 2 , 72 8 , 38 9 11 . 03 7 , 10 9 18 , 09 2 , 08 1 23 6 , 50 1 22 4 , 57 3 13 0 . 94 5 70 9 37 3 81 4 , 38 5 82 5 , 26 8 28 2 . 10 2 33 4 , 82 8 84 0 , 88 4 41 8 , 8 1 9 TH E R M A L F U E L B U R N E X P E N S E Ce n t r a l l . De v e J o h n s t o n 36 , 83 3 35 6 19 5 , 04 8 55 5 . 35 9 46 0 70 9 . 88 8 46 9 . 29 0 67 3 59 8 23 1 55 1 11 6 , 21 8 34 4 . 63 4 97 4 , 74 5 72 1 , 23 0 88 2 , 28 3 Jim B r i d g e r 11 3 , 99 7 78 2 12 8 , 50 1 10 , 67 4 , 53 6 11 1 , 17 9 26 4 , 72 4 30 2 , 83 1 10 , 17 4 , 4 7 2 53 6 , 87 1 14 5 , 73 1 37 2 , 09 2 90 8 , 0 6 7 49 3 , 42 5 88 3 , 55 1 Wy o d e l f . 18 , 97 0 , 42 2 63 5 23 5 65 1 , 49 2 63 5 96 9 70 9 24 6 64 6 55 2 07 1 , 39 8 92 4 . 44 1 92 2 , 28 8 42 6 , 61 2 42 5 , 33 3 33 6 , 39 3 16 3 . 26 1 Co I s b 1 p 81 3 , 97 6 88 0 , 41 2 47 4 , 69 2 56 8 , 97 3 23 9 . 60 0 60 2 . 13 3 45 4 , 26 9 &5 9 , 30 7 72 6 , 29 2 69 3 , 06 1 61 9 , 55 0 47 0 , 28 9 60 5 , 37 9 Ce r b o n 99 3 , 56 5 76 1 , 73 4 77 6 31 2 69 6 36 7 79 8 31 6 77 2 , 16 1 76 4 16 7 75 8 , 36 4 72 9 . 92 1 78 7 , 97 0 73 9 , 50 4 62 4 . 81 5 76 1 . 93 1 No u g h t o n 58 . 73 1 . 70 6 32 9 , 60 9 90 4 , 82 4 48 4 . 43 7 66 4 , 02 5 07 6 , 10 1 73 6 . 29 5 58 6 75 8 90 4 13 6 64 0 , 89 0 07 0 57 5 46 1 , 69 2 68 6 36 4 Hu n t i n g l o n 43 , 62 1 , 59 6 15 0 , 63 8 66 7 72 6 64 8 , 37 6 32 3 , 77 9 43 8 , 31 7 1.9 7 0 10 8 69 6 , 22 7 00 6 , 77 9 33 0 , 21 5 62 0 , 92 3 05 4 , 60 9 31 1 , 89 6 Hu n t e r 14 2 70 5 54 4 . 69 0 05 2 , 68 0 12 , 67 6 , 23 7 31 3 , 92 3 47 3 , 73 2 65 0 , 73 4 62 2 , 03 7 07 0 , 79 7 55 5 , 41 7 36 3 . 51 9 04 1 , 65 4 57 7 , 30 5 Blu n d e l l 68 8 73 6 31 9 , 33 4 30 1 , 80 1 31 4 . 33 4 32 0 , 26 8 22 4 , 90 1 30 9 99 8 32 8 , 07 7 33 4 , 19 1 31 2 . 78 6 31 9 , 81 8 32 1 , 38 4 29 4 , 02 9 Ch o l l a 38 , 25 7 . 77 7 96 8 02 7 29 5 88 7 85 4 . 78 8 26 7 , 69 4 29 8 , 62 4 07 3 , 86 7 09 0 77 3 44 0 , 25 1 07 5 . 26 7 06 5 , 17 4 01 2 . 37 6 01 6 , 87 1 Cra i g 81 1 . 6 2 2 34 9 , 76 5 03 3 , 88 9 7& 5 . 64 5 50 3 , 76 0 21 7 , 00 9 94 5 , 71 2 07 9 , 00 9 09 8 , 98 9 89 4 . 18 0 12 8 , &5 9 23 7 19 0 46 2 , 36 4 ) Ha y d e n 84 4 , 50 2 60 1 , 02 4 53 6 . 34 5 63 4 , 06 1 37 1 24 6 55 0 , 58 0 61 8 21 0 60 0 , 51 0 64 6 , 35 9 62 1 73 6 54 9 38 8 51 0 . 98 3 80 2 , 10 0 Ga d s b y 58 , 32 2 , 80 6 36 2 62 9 7, 4 0 3 , 60 7 82 4 20 6 47 0 . 51 9 97 8 . 09 2 92 2 , 30 1 55 9 23 6 15 7 , 11 2 51 6 , 26 7 03 2 , 09 8 90 5 , 36 3 19 1 , 37 7 He r m l s l o n 44 6 17 9 77 6 , 54 2 56 1 , 92 5 3,4 2 3 57 4 3,7 9 0 , 11 6 25 9 . 07 0 51 8 34 1 55 3 , 4& 8 64 2 17 5 68 0 19 6 72 9 , 83 0 53 1 . 49 1 97 9 , 45 3 Ja m e s R I v e r Fo o t e C r e e k W i n d Uti l e M o u n l a l n 94 6 01 5 40 9 , 40 9 28 0 , 32 3 53 0 , 04 0 71 6 . 24 4 Jim B r i d g e ' F u e l C r e d i t (2 0 , 54 8 , 44 2 ) (2 , 10 3 28 8 ) (2 , 27 5 , 05 8 ) (9 1 9 92 8 ) (1 , 11 6 , 76 4 ) (1 , 88 9 , 71 9 ) 77 7 07 9 ) 11 8 54 2 ) 29 3 . 62 3 ) 52 9 , 81 3 ) 94 5 32 3 ) 59 7 67 8 ) (1 , 98 3 . 51 1 ) TO T A L F U E L B U R N E X P E N S E 46 7 . 68 4 . 33 0 43 , 88 7 , 89 6 81 7 , 97 8 73 7 , 70 0 83 0 , 42 1 42 1 , 67 5 10 8 , 38 7 38 , 29 4 . 08 9 43 , 84 9 . 59 7 36 , 13 1 , 01 7 40 , 09 2 , 15 9 36 , 87 7 , 25 7 36 , 22 8 , 15 3 -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - == = = = = = = = = = = = = = = = = = = = = = = = = == = = = = = = = = = = = -- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - NE T P O W E R C O S T 21 0 41 6 , 37 5 12 1 , 83 7 , 89 5 10 3 , 37 8 , 53 9 47 , 91 7 , 17 9 89 , 12 8 , 45 5 77 , 8& 5 , 84 8 11 3 , 88 5 , 88 0 20 4 , 59 3 , 23 1 18 5 28 3 12 2 10 8 , 07 0 , 12 2 47 , 21 0 82 2 43 , 32 5 , 04 5 80 , 14 3 , 05 8 -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Ne t Po w e r C o s t I N e t Sy s t e m L o a d 22 . 25 . 4 2 24 . 11 . 24 . 17 . 28 , 44 . 39 . 4 9 25 . 11 . 10 . 12 . Po w e r P I . . 20 1 2 0 0 2 Alt l JR 1 . 14 J d e Pa c l t l C o l p Ac / 1 J s J 1 2 m o n I h s 81 I c l n l l l 2 / 3 1 1 O 1 NE T S Y S T E M L O A D Te m p e r a t u r e A d j u s t m e n t No n n a l l z e d L o e d SP E C I A L S A L E S F O R R E S A L E Bl a c k H i l l s So C a l E e l o o n ( P ) So C a l E e l o o n ( U ) SM U D IP P S a i e Pu g e t P o w o r I I Sie r r a P a c i f i c I I UM P A S a i e CD W R S a l e WA P A S a i e PS C o S l l l e Cle r k S a l e Cle r k S & I S a l e Hin s o n Ble c k H i l l o C e p a c l l y S a l e Sp ~ n g 1 l e l d PN G C Ch e y e m e S a l e De s o r e t S u p p l e m e n t a l De o e r e t D i s p l a c e m e n t Ok o n o g o n UM P A I I S a l e Sp ~ n g 1 l e l d I I Co w l l l z - BH P Cla r k . Hu r r i c a n e S a l e s AP P A - AE P C O Cl6 . e n s P o w e r Gr e e n M o u n t a i n s Aa t h e a d S l I I e BP A W l n d S a i e SD G & E S a l e BP A - Ae t h e e d S a l e Sh o r t T e n n A n n S a l e s Se c o n d l l J ) ' S e l l a TO T A L S P E C I A L S A L E S 20 0 1 52 . 88 9 , 27 8 (3 0 6 , 43 1 ) 52 , 38 2 , 84 7 47 4 , 32 8 54 4 , 52 1 54 4 , 52 1 43 8 11 0 54 4 , 33 4 05 1 , 20 1 45 4 , 58 9 48 , 81 7 81 3 , 20 0 43 4 88 0 15 2 17 8 85 5 , 75 7 14 , 72 5 19 2 , 74 2 17 2 74 0 14 4 , 30 9 24 3 , 38 5 28 , 4 9 7 53 5 13 2 88 4 82 , 49 8 69 , 95 2 87 , 60 0 10 , 34 4 97 6 12 9 84 6 (3 , 14 2 ) 49 8 , 18 0 41 , 83 3 87 5 , 89 0 11 9 28 8 12 , 21 0 , 23 8 30 7 74 2 22 , 57 7 , 85 8 78 5 , 77 8 20 , 41 2 80 8 , 18 8 40 , 07 9 73 2 73 2 71 , 57 4 44 , 89 1 97 , 00 0 38 , 37 6 42 8 52 , 00 0 39 , 4 3 2 95 , 73 4 18 9 , 26 0 24 , 11 5 0 44 , 84 0 80 , 63 5 29 , 97 8 06 0 21 , 31 6 82 0 44 0 12 5 80 0 30 , 08 3 52 , 08 0 80 2 74 , 32 9 61 8 , 03 5 95 2 78 9 , 88 3 Jo n 27 8 , 52 0 (4 3 , 85 5 ) 23 4 , 88 5 36 , 41 7 08 9 47 , 06 9 29 , 15 1 44 , 38 2 67 , 81 5 31 , 76 6 99 3 43 , 7 2 5 35 , 61 6 86 , 54 5 15 2 , 88 0 28 , 53 5 40 , 32 0 67 4 27 , 02 1 36 8 19 , 25 3 82 0 72 0 12 5 52 0 (9 , 52 4 ) 04 0 24 0 67 , 18 5 71 9 , 78 8 6, 0 7 8 88 7 , 64 1 Fo b 30 8 , 52 3 20 , 53 8 32 9 , 05 9 40 , 12 8 44 , 50 0 50 0 22 , 57 5 28 , 28 8 62 , 45 0 37 , 19 8 30 2 44 , 71 2 28 , 83 2 88 4 14 5 , 08 0 45 9 44 , 84 0 88 8 1, 0 4 3 79 5 31 8 51 9 44 0 88 8 52 8 (8 , 80 1 ) 52 , 08 0 70 8 40 0 74 6 , 20 4 51 , 35 3 87 9 , 88 3 Me r 10 7 , 17 4 (8 0 , 37 8 ) 04 6 , 79 6 38 , 73 1 43 , 43 4 43 , 43 4 23 , 32 0 48 , 10 2 67 , 42 0 32 , 95 2 35 3 45 , 05 5 28 , 10 7 92 , 78 4 14 3 , 00 9 63 5 43 , 14 0 (1 0 , 4 0 9 ) 08 8 02 0 42 3 30 0 49 5 19 0 98 7 13 , 36 0 (4 , 42 8 ) 50 , 33 0 44 1 71 , 90 0 00 1 1 , 30 3 18 , 85 2 84 5 , 32 8 Ac t u 8 I Ne t P o w e , e o s t E n e r g y A n a l Y l l o (M W H ) Ap r 34 5 , 91 4 (7 8 , 71 8 ) 26 9 , 19 8 40 , 27 7 42 , 77 4 77 4 22 , 89 5 48 , 36 3 79 , 75 5 28 , 05 7 93 9 48 . 20 0 33 , 03 2 13 8 13 4 , 92 4 37 0 91 5 37 0 93 5 49 8 68 9 44 0 10 5 14 , 16 0 08 0 80 9 74 , 37 8 83 0 , 11 8 8 38 , 73 1 87 4 37 1 Ma y 28 9 , 32 3 (5 0 , 57 8 ) 23 8 , 74 5 23 2 79 8 44 , 79 6 21 1 , 36 5 47 , 49 5 63 , 47 5 51 1 16 6 43 , 60 0 35 , 7 6 0 94 , 93 6 24 4 24 0 25 0 80 0 85 1 72 8 22 . 17 9 60 7 20 0 91 3 13 , 38 0 50 , 4 0 0 87 8 72 , 00 0 83 6 , 03 5 14 , 99 9 57 7 , 82 4 Ju n 81 1 , 32 8 (3 2 , 70 0 ) 57 8 , 62 8 39 , 50 9 55 , 80 0 55 . 80 0 43 5 4& , 08 4 99 , 72 5 05 7 30 0 52 , 60 0 39 , 43 2 10 1 , 01 0 48 , 38 0 84 6 23 , 01 1 4 77 7 12 5 21 1 , 35 5 88 0 44 0 99 0 04 6 12 . 80 0 52 , 08 0 95 6 74 , 40 0 11 4 , 29 6 36 . 39 4 03 2 , 18 5 89 1 , 00 3 (5 1 1 95 4 ) 63 1 04 9 41 , 31 1 56 , 67 7 58 , 87 7 54 , 20 5 47 , 15 0 10 4 , 16 0 44 , 75 4 11 5 56 , 54 0 39 , 43 2 10 1 , 04 0 98 5 24 , 33 7 97 6 31 , 4 9 1 50 1 44 0 02 3 18 , 04 8 52 0 52 . 08 0 92 4 74 , 4 0 0 22 9 42 3 16 , 04 5 08 5 , 85 3 Au g 18 5 , 09 4 (3 5 , 48 9 ) 14 9 , 60 5 38 . 26 1 39 , 20 0 39 , 20 0 27 5 10 0 , 28 1 75 8 11 1 3 52 . 92 5 38 , 16 0 94 , 95 3 17 , 15 1 19 , 35 7 11 , 40 2 52 8 22 , 00 4 10 , 31 4 13 2 20 0 88 0 19 8 (1 2 47 2 ) 40 0 57 6 72 , 00 0 41 7 . 15 8 30 , 84 2 13 9 59 8 So p 14 8 , 34 3 37 8 15 3 , 71 9 21 1 0 37 , 38 9 37 , 38 9 42 9 85 , 23 2 10 4 , 16 0 34 , 73 5 88 3 57 , 85 0 48 5 98 , 95 4 81 5 18 , 22 5 21 , 08 0 2, 4 9 9 19 8 45 0 57 7 84 0 11 . 8 2 0 54 8 74 , 50 0 40 , 23 0 17 9 , 86 6 42 , 26 3 97 5 . 20 3 Oc t 17 0 , 91 8 32 , 15 4 20 3 , 07 2 39 . 38 5 35 . 97 8 35 . 97 8 25 , 37 8 49 , 11 3 10 0 , 52 0 54 , 00 0 09 4 53 , 80 0 38 , 16 0 94 , 4 2 1 55 0 20 , 39 1 11 , 48 4 1; 6 2 1 1 1,4 9 8 55 3 20 0 61 1 14 , 26 0 13 , 02 3 69 7 oo o 38 , 68 0 39 6 , 35 8 18 , 69 6 13 8 , 85 4 No v De e 74 7 , 38 2 (2 5 , 23 7 ) 72 2 , 12 5 39 , 71 0 17 2 37 , 17 2 69 , 70 8 58 , 45 4 10 4 , 44 0 55 , 42 5 14 1 1 62 , 39 3 39 , 43 2 97 . 79 7 86 0 16 , 40 0 24 . 38 7 92 4 10 , 71 7 54 0 44 0 88 0 12 , 66 7 45 8 74 , 40 0 40 , 17 6 11 2 , 82 7 31 . 51 7 96 4 . 04 5 == = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = 71 1 . 40 7 TO T A L R E Q U I R E M E N T S 75 . 24 7 13 4 57 5 , 45 9 94 8 , 16 1 11 8 8 , 18 8 85 2 . 50 2 02 0 . 28 5 88 7 , 14 7 84 3 , 52 3 78 8 , 65 6 32 4 . 89 0 12 3 . 54 8 30 7 , 57 2 -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - UR C H A S E D P O W E R & N E T I N T E R C H A N G E BP A S u p p l e m e n t a l C e p a c l l y Bla c k H I l l I C e p a c l l y P u r c h . . e Co G e n l J e m e s R i v e r Do u g P U D S e t U e m e n t MId C o l u m b i a Co n a d l o n E n 6 6 o m e n t CS P E Co I o c k . . " Gr a n t C o u n l y US S R G r e e n s p ~ n g e PG E C o v e IP C Re - F. C o n ~ a c t s - P P & L T~ S t a t e P u r c h . . e So u t h l d e h o E x c h o n g e AP S P . . . c h . . . T~ S l a t e E x c h a n g e SC E P o r c h . . e BP A E x c h a n g e Av l s l a S u m m e r P u r c h . . e Po w e r P I a . 20 1 2 0 0 2 86 2 33 9 81 7 40 , 22 5 43 3 , 78 4 (7 5 , 61 6 ) 81 , 12 5 (1 9 0 . 61 6 ) 87 . 60 0 93 4 23 , 57 2 (4 8 , 4 5 4 ) 60 0 59 5 27 4 24 7 (1 3 15 1 ) 43 4 06 0 (1 6 , 63 7 ) (1 , 13 3 ) 10 9 75 8 27 0 30 , 88 0 13 5 17 8 76 7 (6 , 84 3 ) 78 5 (2 4 . 37 3 ) 39 4 07 6 (7 , 02 3 ) 45 . 86 9 50 9 (7 , 17 0 ) 45 . 10 0 21 , 92 5 28 , 59 8 45 2 14 4 , 26 5 (5 , 95 2 ) 03 2 (2 2 , 71 8 ) 99 0 88 4 92 9 18 , 4 2 8 (2 , 76 9 ) 02 5 18 , 08 7 (7 0 0 ) 02 8 87 8 13 6 , 06 8 (6 , 63 1 ) 61 7 (2 1 , 14 8 ) 81 8 02 8 15 2 ) 55 9 17 , 15 4 31 6 ) 11 2 72 5 22 , 40 8 (6 0 ) 30 . 94 8 67 2 10 5 91 8 (8 , 05 8 ) 13 7 (1 6 , 88 3 ) 7,4 0 9 97 7 85 8 ) 55 , 25 1 19 , 63 7 (9 2 ) 08 5 (2 5 24 3 ) (8 4 ) 27 , 97 7 70 7 42 2 42 5 ) 35 0 (1 1 70 8 ) 34 2 02 8 (3 , 84 6 ) 38 3 06 7 24 4 75 , 00 0 (2 8 , 09 1 ) 14 4 88 4 31 , 15 1 23 9 11 0 . 32 7 (6 , 20 6 ) 14 5 (5 0 4 ) 91 1 6 98 0 (4 , 85 9 ) 52 , 60 7 21 , 97 6 62 5 (2 5 , 20 0 ) 20 , 20 3 (8 4 ) 33 , 89 0 90 3 77 . 50 1 (6 , 26 7 ) 47 0 97 2 ) 27 8 02 8 (4 , 96 4 ) 56 , 0 7 8 30 7 84 0 (2 8 . 40 0 ) 39 8 29 , 48 1 83 5 12 0 33 2 (6 , 42 5 ) 47 0 (1 6 . 85 6 ) 55 9 02 6 (4 , 67 5 ) 21 1 6 42 5 75 0 (2 6 , 04 0 ) 38 , 93 2 (8 0 ) 28 , 16 2 17 2 10 9 , 69 7 (6 , 06 7 ) 14 5 (1 6 , 88 0 ) 09 6 11 8 0 (5 , 28 8 ) 47 , 28 3 24 , 21 5 (3 8 ) 35 0 (2 5 , 20 0 ) 21 1 , 22 5 53 1 25 5 33 0 10 7 . 60 7 (6 , 43 0 ) 35 9 (1 7 , 61 1 0 ) 5, 9 0 0 03 0 45 , 97 7 26 , 07 6 24 . 13 9 (1 2 3 ) 27 8 20 . 80 7 05 1 12 7 21 5 20 1 ) 14 5 (1 8 , 00 3 ) 72 8 U8 0 (3 , 46 3 ) 42 , 43 0 63 0 (1 , 11 1 0 ) 32 5 25 , 15 0 (3 1 0 ) (4 8 ) 13 9 23 , 82 4 85 1 15 0 . 88 9 21 1 1 ) 47 0 (1 7 , 32 3 ) 6,0 9 0 93 4 55 3 (6 . 5 0 8 ) 95 3 29 . 80 5 19 . 43 5 63 0 At t JR 1 . 14 . xll Av i o l a E x c h o n g o 12 , 90 0 (7 , 71 2 ) (6 , 98 8 ) 20 0 35 0 85 0 5,4 0 0 Go m S l a t s 34 , 29 7 07 3 11 , 88 8 10 , 94 6 41 2 GS L M 35 , 08 7 28 9 02 7 53 6 53 4 13 2 58 9 QF C o n t r a c t o - U P & L 45 6 , 09 9 39 , 83 1 35 , 37 3 44 , 35 7 27 , 34 8 32 , 67 1 41 , 92 9 42 , 92 3 38 , 73 5 31 8 37 , 14 8 84 5 43 , 02 3 IP P P u r c h o s e 54 4 , 33 4 44 , 89 1 44 , 38 2 28 8 48 , 10 2 48 , 38 3 47 , 49 5 08 4 15 0 23 2 49 , 11 3 56 , 45 4 Bla c : t l H i l l s S U i p l u o He r m l o t o n P u r c h a s e 94 9 , 37 6 17 2 , 07 3 17 1 , 58 8 15 2 , 35 7 18 8 , 91 2 14 1 39 5 18 2 , 02 8 18 0 , 73 0 18 4 , 23 2 18 4 , 22 3 18 7 , 99 4 15 1 , 84 5 17 2 , 21 9 De o e r e t e x p a n s i o n 19 8 82 5 18 , 89 0 42 8 18 7 17 , 81 0 19 , 05 8 13 , 81 0 22 , 18 4 14 , 78 8 13 , 86 6 18 , 18 0 17 , 85 8 23 0 De s e r e l R e o o u r c e P u r c h o s e 48 , 02 3 38 1 (4 , 88 4 ) 17 , 22 1 12 , 95 1 (1 4 , 73 1 ) 06 0 ) 18 2 98 3 29 , 93 9 28 8 (1 4 , 44 8 ) AP S E x c h a n g e 09 2 14 3 87 3 89 , 12 0 (7 8 , 32 0 ) (1 3 7 90 8 ) (1 4 2 , 40 6 ) (1 4 3 , 09 8 ) (8 9 , 27 0 ) 78 , 23 8 13 8 , 24 0 14 2 , 82 3 Hu n 1 c e n e P u r c h a s e 11 2 19 8 10 2 10 4 Fo o l e C r e e k Re d d i n g E x c h a n g e (1 7 12 3 ) 84 4 10 , 15 3 11 , 77 3 88 4 (8 , 75 2 ) (8 , 87 7 ) (7 , 47 3 ) (1 9 , 09 0 ) (8 , 87 0 ) (1 8 20 3 ) 83 3 87 5 Tr a n s A J I a P u r c h o s e 17 8 42 5 14 1 , 55 0 12 6 33 8 14 0 25 6 13 5 , 88 5 14 7 07 5 20 7 , 95 4 20 9 , 80 8 21 5 94 7 20 4 , 75 0 21 4 , 32 1 21 5 , 73 2 21 7 , 03 1 Fo o l s C r e e k I V P . . . c h 84 3 08 9 91 9 85 9 89 3 72 1 48 5 35 3 52 4 Er I o n P u r c h o s e 11 3 , 20 0 10 , 4 0 0 80 0 10 , 80 0 10 , 40 0 40 0 10 , 40 0 10 , 40 0 10 , 80 0 60 0 10 , 80 0 9, 6 0 0 Ga d s b y P e e k e r s 18 2 , 96 0 31 , 80 3 27 , 14 7 33 , 84 1 34 , 18 9 11 7 27 , 08 3 Sh o r t T e r m A r m P u r c h a s e s 14 , 31 2 , 36 6 12 4 , 23 4 05 5 , 4 8 6 95 3 , 58 3 52 8 , 03 1 02 9 , 49 2 01 4 , 50 9 43 9 , 88 8 59 2 , 08 8 49 9 89 2 85 3 , 35 2 10 5 , 20 9 11 6 , 82 2 Se c o n d a r y P u r c h a o e o 87 2 , 77 8 33 1 , 33 7 18 3 88 5 15 2 67 8 85 , 48 0 19 6 , 72 2 18 6 83 0 14 7 , 51 1 18 4 , 71 3 (7 , 42 8 ) 13 5 , 41 0 10 9 , 15 6 20 6 50 0 TO T A L P U R C H A S E D P i N & N E T I N T . 25 , 01 0 , 62 2 35 1 , 48 6 02 0 , 44 3 87 0 16 9 32 1 , 12 2 80 6 , 42 1 80 0 , 61 0 18 2 , 47 5 38 0 , 30 4 08 9 42 3 1.8 5 8 , 57 4 08 4 76 8 24 4 , 82 7 CO A L F I R E D G E N E R A T I O N Ce n t r e l l a Da v e J o h n s t o n 83 3 72 6 48 8 , 50 8 47 1 , 84 2 54 0 , 62 8 46 9 , 18 8 44 5 , 6 3 9 38 6 , 77 5 46 8 , 80 3 43 0 34 0 49 0 , 78 3 51 2 , 13 8 48 6 , 04 3 48 7 08 5 Ji m B r i d g e r 10 , 48 8 28 1 98 0 , 09 2 87 3 , 34 5 92 8 58 8 73 7 40 9 81 8 , 87 8 93 2 , 39 5 95 4 , 80 4 90 4 , 45 5 74 8 , 19 5 78 3 , 91 8 92 7 , 38 3 91 8 , 84 1 Wy o d a k 25 1 , 81 8 19 9 , 21 9 18 8 , 67 8 19 0 , 48 1 17 4 , 53 6 17 6 , 31 9 19 4 , 02 5 19 8 97 8 18 8 , 43 8 19 3 , 83 0 20 4 , 25 1 17 8 , 8 1 7 17 0 , 44 8 Co I s t r t p 07 8 , 27 7 28 1 97 , 33 0 80 , 41 3 50 , 23 9 75 , 52 3 88 1 10 2 , 01 5 10 8 , 49 8 98 , 78 0 10 5 08 5 38 9 93 , 88 5 Ca r b o n 37 2 71 5 11 0 , 57 4 11 3 , 59 2 11 4 , 13 5 12 0 , 09 6 11 1 , 96 9 12 0 , 38 1 11 8 , 81 3 11 7 02 3 11 7 , 83 8 11 8 , 79 1 93 , 43 3 12 0 , 27 2 Na u g h t o n 34 9 , 69 7 45 7 , 20 1 40 4 , 82 3 46 1 , 73 1 48 4 , 30 1 48 8 , 0 5 1 44 7 , 21 8 44 7 , 31 4 43 3 , 18 6 41 6 , 87 7 44 9 , 68 7 40 8 , 81 6 47 2 , 71 2 HL J ' I U n g t o n 24 1 , 90 9 59 4 , 40 9 52 8 , 09 1 58 4 , 93 8 56 9 , 45 1 35 3 07 5 26 8 , 66 1 55 4 , 50 7 56 8 , 96 7 56 6 08 8 56 1 , 92 9 58 5 , 70 8 54 0 , 06 9 Hu n ! e r 93 9 83 8 48 4 , 56 1 39 9 , 53 3 44 8 , 12 2 15 4 , 79 4 88 7 , 83 6 69 4 , 55 2 72 6 , 27 7 78 4 , 38 8 72 3 59 8 69 0 , 48 4 83 4 , 44 4 57 1 , 43 1 Bl u n d e l l 15 2 , 74 2 71 6 38 7 83 8 97 2 (1 2 9 ) 14 , 84 7 18 , 0 2 5 18 , 31 8 13 , 05 7 15 , 88 8 14 , 00 3 10 , 08 4 Ch o n a 77 9 08 8 19 1 , 28 3 23 6 , 20 9 18 8 , 45 0 25 8 , 35 6 26 1 94 2 24 4 , 83 7 25 2 , 72 1 28 1 , 59 2 25 2 , 31 0 24 1 92 9 18 0 . 0 0 1 23 1 , 85 6 Cr a i g 24 8 , 32 2 12 0 , 84 3 10 8 , 77 7 74 , 19 1 58 , 76 2 11 5 , 18 2 91 , 40 5 10 6 , 99 8 12 2 , 15 0 10 5 . 5 2 1 11 3 , 94 0 11 8 , 5 3 9 11 2 , 01 4 Ha y d o n 82 4 , 38 1 54 , 68 9 49 , 47 9 57 , 68 1 37 , 33 8 50 , 90 7 54 , 32 9 54 , 81 1 48 3 55 , 79 6 49 , 81 0 44 , 33 4 57 , 52 4 Ga d s b y 95 5 , 47 6 90 , 48 6 10 3 , 96 2 99 , 08 9 10 9 , 41 7 10 4 , 57 4 07 8 84 , 99 2 68 , 33 0 78 , 79 8 47 , 88 8 20 , 19 2 32 , 87 0 He r m l o t o n 93 9 , 98 4 17 2 07 3 16 2 , 25 6 15 2 , 41 1 18 8 , 91 1 14 1 , 31 3 18 2 , 02 5 16 0 , 72 9 18 4 , 22 8 18 4 , 17 8 16 7 , 99 6 15 1 84 3 17 2 , 21 9 Fo o t e C r a e k W i n d 10 9 88 8 12 , 08 9 11 , 13 9 73 8 03 7 10 , 00 4 56 0 13 9 77 5 87 3 14 , 11 0 08 4 34 0 Utt l a M o u n t a i n 31 , 98 3 93 2 83 4 10 , 08 4 13 3 Tr o j a n (3 4 2 ) (4 3 ) (3 4 ) (3 7 ) (3 2 ) (2 4 ) (2 0 ) (1 9 ) (1 9 ) (1 6 ) (2 6 ) (3 0 ) (3 8 ) TO T A L C O A L F I R E D G E N E R A T I O N 47 , 17 7 , 76 1 00 4 , 99 9 75 9 , 21 1 92 2 , 37 3 39 2 , 75 5 81 8 , 85 9 78 9 74 9 24 8 , 70 7 21 5 , 18 8 05 7 , 21 0 05 9 38 4 91 3 , 88 1 99 5 , 50 5 TO T A L S Y S T E M H Y D R O 05 8 75 1 21 8 , 97 4 18 8 50 7 19 5 , 84 4 23 8 , 82 5 39 5 , 00 5 27 8 , 78 8 21 2 , 34 1 19 1 , 18 4 17 8 , 05 7 20 5 , 80 8 30 8 , 94 3 47 1 , 07 5 -- - - -- - TO T A L R E S O U R C E S 75 , 24 7 , 13 4 57 5 , 45 9 94 8 , 18 1 88 8 , 18 8 95 2 50 2 02 0 , 28 5 88 7 , 14 7 84 3 , 52 3 78 8 , 85 6 32 4 , 89 0 12 3 , 54 8 30 7 , 57 2 71 1 , 40 7 -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - == = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = == = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = = -- - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - Po w a r P I , !I 2 O J 2 0 0 2 DR 1 . 14 J d s Pac:ifCoqJ Semi IvIooaI Study Period end8d 03I311V1 POIMac SUIy ResuIb Net Power Cost Analysis ($) Type I 03101 Type II 03101 Type III 03102 SPECIAL SAlES FOR RESALE Black Hils 318829 815 368 14.682394 So CaI Edsm (P)138730 856.885 903529 So CaI Edsm (U)138730 956.885 903529 SMUD 678 118 203442 203440 SiemI 883,748 IPP Sale 23,228536 228536 824 290 Puget Power II 784497 456516 52,5&4,330 SiemI P- 821 304 285461 24.806 822 UMPA Sale 454 657 474 166 661 709 Nevada (base)(44887) COWR Sale 587 242 34.385 048 634 958 WAPA Sale 18,307 886 511 360 856 960 WAPA II Sale 836 274 PSCo Sale 739663 073 683 469654 BYEB Sale 95 385791 Reddi1g Sale 491 415 Qark Sale 627323 214728 129.626Iha1538539 Black Hils Capacity Sale 794,181 794 181 690963 Black Hils Slaage 26.100 Spmglield 722 136 819,711 915.940 PNGC 535374 455,788 738493 01eyeme Sale 104 704 Desefet SUpplemental 546 637 183 701 1,713 458 Okanogen 682566 682 566 245,407 UMPA II Sale 692 313 692,313 493.376 PIei1s EIedric G&T 650,714 Spmglieldll 759,538 2,768 238 (145,518) CowIitz-B1P 182 098 182.098 300,124 Qark-584 348 Qark-428480 428 480 428480 Ibricsne Sales 272244 272,244 177,299 APPA-A8"CQ 687609 687609 939538 APPA-8J#2 722319 APPA-Mesa 536575 atizeno Power 016403 164484 141324 Green MCU1Ieins 695546 Ralheed Sale 624820 624820 5&4,765 BPA Wood Sale 087647 350665 286830 SDG&E Sale 14,385954 14,385954 857000 Slut T enn Ffln P 669793463 737,659440 286040903 Slut Tenn Ffln Inlertie 303740,000 327823 711 203264588 Slut T enn Ffln U 529349205 582,796.843 549.171 200 Seocndary Sales 383 136 664 663743 614 138,582 506 Naveda Feu Caners 128.422 331 184 627 690 387 915 Northwest 202.927460 361,053.610 613 518sw-786 873 118 062.314 581 073 -- -,----- --- . TOTAL SPECIAL SAlES 405 694 033 2785 278538 580.148018 PURCHASBJ POWER & NET INTERCHANGE BPA Peaki1g Pwd1ase 100.000 160000 439500 BPA Entitlement CapaQty 124 124 848 BPA Supplemental Capeaty 124 124 25,848 Bleck Hils Capacity 617,338 563413 440 000 eaGen/JOllIes River 16,194783 228 754 306 371 Mid QUnbia 16.277 185 727 130 727.130 Grant Ccu1ty 066000 066 000 066 000 PGE Cove 227532 227532 195 752 USSR Greenspmgs 529 894 F. Con1rods - PP&L 55.293.885 293 865 651 423 TriState 804 818 944 234 210 476 Sarth Idaho Exthange (165 112)(165 112)(558,651)APS-933 845 814 588 639.677SCE-133290 133290 688.205 A...18 Slanmer PLn:hese 097 817 097917 566,474 Gem State 405 401 405401 405401 GSLM 584 458 584458 805307QFCmIr_-IP&L 34,728.205 52,044683 700541IPP-23,228536 228,536 519634 Black Hils s..pius 15.830073 Hennistan 225633 241070 454 966 Degeret ArnIaI 609 177 Desefel Mmlhly 682640 Desefet Eopension 426222 458.429 17.302 839DesefelNF-383477 535.451 723 344 Ibricsne 32,822 822 834 L TF Reserve 733 167 508 195 472 000 TrensAIta l'u'chese 73,721 085 162 215 020 096 En-on 278,200 096,200 096 200 Foote Creek IV P\a'ch 209 834 629 522 191 003 DSM (Load ~ent)419442 419 442 419 442 Rodt River Wood 532,5&4 STF PPL 345 749428 356 670,931 471,151.885 STF Ptn:heses IPL 453 841,284 356 193,196 745.822621 Seocndary 332,826.638 281 525.493 197 797 355 -------- TOTAL PURCHASBJ PW & NET IN 2,633 079,345 2514.981.914 925070085 WHEB,ING & U. OF F. EXP8'ISE Power PI8rring 02l2Ol2OO2 12:35 PM Pagel AIIach IIPA DR 1.14"" . lIIonnolzed MII"-2001 81"'1-1.181,592 688 880 359836 0Iher 11346&578 104357 860 100587564 TOTAl.. WHEB.ING & U. OF F. EX 114848 170 106,04e 740 100957,200 THERMAl.. AJB. BURN EXPEHiE CermIia 840,070 Daw JdnIta1 453 718 29,453089 847.227 .!in Bridger 85.510 571 85,402106 484,007 19,258206 587944 886,460 30935&515491 280,410 CIIbm 157193 7707:11 187.210 910721 993714 56,001.984 Ib1mgIon 751.724 752,458 752458 50,252588 688,901 084884 933014 933015 933,015ads86068831,550 160 520,937 QIIig 494 158 484 159 484 159 Haydon 880262 881 157 881.15)'G-.,156880 701 022 579401 423,563 299 454 925 288 Call 23,181005 880 100 729,750 TOTAl.. AJB. BURN EXPEHiE 482273 739 471.015 107 458407 327 ------------------------------------------------------------- NET POWER COST 824307 221 306 765 223 904206 583 -------------------------------------------------------------- NeI_eosllNelS)'s,.",Load 15.5.76 16. -Plaming 02l2Ol2OO2 12:35PM Page 2 AItac:h liP" DR 1.14"" - Namaized MII"-2001 PaatiColp PDMac Sludy Semi Study Ne! Cost Energy Analysis Period ended 03131101 (MWH) Type I Type II Type III 03101 03101 03102 NET S'IS1EM LOAD 259547 53,259547 259 547 SPECIAl SAlES FOR RESAlE 8I8dI ... 497013 459 822 466 159 So CaI Edson (P)618121 618,121 632 790 So CaI Edson (I))618,121 618,121 632,790 SMUD 378650 350401 350399 SiemI Poc:i1ic 886 IPP Sale 530561 530 561 504 576 Puget 002925 002 925 124,165 SiemI P8cific II 450 168 450 168 480336 lHPA Sale 739 739 52,819-(base) COWR Sale 600,227 600,227 656.428 WAPA Sale 481 305 453 480 4&4,280 WAPA II Sale 404475 PSCo Sale 156425 156 425 174245 BYe! Sale 95 131 655 Reti1g Sale 243 399 Cork Sale 41883&4/8836 39&267 ...... 286,731 8I8dI ... Capacity Sale 450 450 39,321 8I8dI ... Skrage 525 SpmgfieId 240 082 240,082 190 955 PNGC 391445 375864 43,140 QJeyeme Sale 872 86& Doser.t ~enlal 556 6&3 555314 12,983 45,252 lHPA II Sale 141 212 141212 187 224__G&T 138203 SpmgfieId II 144 285 144285 195 CcMiIz-B1P 812 66,812 75,791 Cork,961 Cork-600 600 87,600 Ibricano Sales 723 723 332 APPA-AEPCQ 114146 1/4 146 640 APPA-ED#2 32,785 APPA-Mosa 9!14Citizens-130712 130.712 128,754 Groen 150481 Aolhead Sale 613200 613 200 612047 BPA Wild Sale 684 684 161 SOG&E Sale 874526 874 526 6110000 Shat Term 11m P 887831 887 831 749443 ShatTerm 11m 687462 687 462 206 130 Shat Term 11m U 426,450 426,450 806260 Sales 716228 764 300 285014 Feu" Comers 144783 468 830 271901 Nor1hwosI 278 126 484,141 n5,O98~lnIortie 226,291 702,733 186569 Sooondory Losses 67,029 108,596 446 TOTAL SPECIAl SAlES 362,631 913556 187496 ----------- n______---nn_____-- --------- n___-__n-nn______- TOTAL REQUIREMENTS 622 178 173103 71,447 043_n______--n______---_n____--_-----_____n n______----n___--_- PURCHASED POWER & NET INTERCHANGE BPA ~enlal CapociIy 8I8dI ... Capacity PIrohoso 041 041 CoGen/JIm" River 358431 358431 378 466 Mid CaUnbia 1.910681 910562 910 518ear-. _enl (76 331)(76 331)(77,286) CSPE 83,639 83,639 331 (187 431)(187431)(198,661) Gnri County 87,600 600 87,600 PG E Cole 084 084 632 IPC RoI.rn (85 998)(85,998)(82,735) USBR Greonsprings 286 F. CaI1rocb - PP81.504528 504528 559 924 TriS1Bte Pu'd1oso 244520 244520 332 763 SaJth Idaho Eotd1ango 12,451 12,451 157 IIPSPud1aso 690,025 690,025 522,085 Tn Slate Eotd1ango (17 988)(17898)(1.241)scePud1aso 161930 161,830 108 BPA Eotd1ango (153,975)(1)(1) AvislB Sllnm... Pud1aso 82,800 800 110040 AvislB Exd18nge (38225)300 300 GIm SlBte 998 898 325 GSLM 361 361 911 OF Ca1nds - '-"81.485525 485525 485525 IPPPud1aso 530561 530561 495500 8I8dI ... SurpUi 169085 Reti1g Pud1aso 105545 Hennislm Pud1aso 1.968569 968,569 958 Deserot 121498 Deserol Monthly 26,724 Dosorol Eocpansion 208907 208,907 189981 DosoroINFPud1aso 523 523 27,694 lIPS Exd18nge 512)(4,512) Ibricano Pud1aso 026 026 964 P- PlOI'IW1g 0212012002 12:35 PM Page 3 AIIBch IIPA DR 1.14.m - Nonnolizod M...-2001 Foote Creek 106,867 106 687 117 065 Redc81g Exd1ange 747 610)095) Translllla Pu"chase 717 138 200,498 437,333 Emn P\n:hase 800 122800 122,800 Foote Creek IV Pu"ch 829 485 270 River WOK!195 STF PPL 12,735 801 213346 470120 STF lPl 539,090 940186 686184 Sec:mBy 073 103 782,471 444,235 TOTAL PURCHASED PN & NET IN 639737 28,491 133 18,274 191 COAL ARED GBIERATION Cen1raia 396962 Dave JDlmIal 569641 569522 569522 Jin Bridger 10,842,882 832,716 843008 WyOOM 143433 143,433 143433Cds~040479 040429 040429 Carbon 314073 314,112 314,112 NouIt1IaI 418 132 420398 421 197 Ib1Ii1gIaI 829,575 829687 829 687 144,989 202,436 202436 182,863 162,863 162 863 540517 540,517 540517 CnIig 336048 336,048 336,048 Hayden 558 316 558,491 558,491 Gadsby 859 293 973 6119 377,221 Hermislal 922,652 955 905 931,569 PaQficWestWOK! Trqan -- TOTAL COAL ARED GBIERATIO 079,955 780 156 270 443 SYSTB.I HYDRO System HyIto 902 555 902,436 902,363 Draft From SIDrage (622) TOTAL SYSTB.I HYDRO 902,586 901 814 902 409 ---------------------------------------------------------------- TOTAL RESOURCES 82,622 179 173 103 447 043 ---------------------------------------------------------------- P....,.1'IanW1g 02I20I2O02 12:35 PM Page 4 Allach IIPA DR 1.14Jds - Nonnllized M...-2001 PacifiCorplP AC-02- February 5 , 2002 lIP A Data Request No. 1. lIP A Data Request No. 1.15: In a format similar to Mr. Widmer s Exhibit 4 please provide a copy (hard and electronic) of the Company s Net Power Cost as utilized by:a. The Utah Commission in its Order in Docket No. Ol-035-01. The Oregon Commission in its Order in Case UE-116. Response to lIP A Data Request No. 1.15: The information requested is provided in Attachment lIP A No. 1.15a. The final net power costs for Oregon Docket No. UE 116 is $595 million based on a settlement. As such a breakdown was not adopted by the Commission. However, in the Company s filing in Docket No. UE 134, the categories of the $595 million net power costs are pro-rated based on the last net power cost studies in Docket No. UE 116, which is provided as Attachment IIPA No. 1.15b. Witness: Mark T. Widmer IDAHO CASE NO. PAC-O2- PACIFICORP lIP A DATA REQUEST ATTACHMENT IIPA 1. Pa c i f i C c w p Ex h i b i t A i Ty p e , U t a h Ne t P- . . C o a l A n a l y s i s 12 - Mo n t h En d i n g 0 9 / 3 0 / 0 0 ($ I Or d . . e d N P C To l a l Ja n Fe b Ma r Ap r Ma y Ju n Ju l Au g Sa p Oc t No v De e -- - - - -- - - -- - - -- - -- - -- - -- - - - -- - -- - -- - - SP E C I A L S A L E S F O R R E S A L E Bla c k H i l l s 46 1 , 31 7 21 5 , 4 2 6 18 2 , 88 9 22 1 , 43 2 20 3 , 73 2 20 4 , 4 1 9 20 4 , 30 2 21 1 , 97 1 20 7 , 74 6 20 4 , 65 0 20 6 15 0 19 2 , 97 6 20 5 62 3 So C a l E d i s o n ( P ) 29 , 63 9 , 88 8 58 3 , 18 3 36 3 , 39 2 27 7 , 27 1 23 3 , 56 4 28 7 . 16 6 33 4 98 9 53 5 , 46 7 59 2 . 57 7 49 6 64 9 65 4 21 4 61 9 . 97 3 66 1 , 26 5 So C a l E d i s o n ( U ) 63 9 , 88 8 58 3 , 18 3 36 3 , 39 2 27 7 , 27 1 23 3 56 4 28 7 , 16 6 33 4 , 96 9 53 5 , 46 7 59 2 , 57 7 49 6 84 9 65 4 , 21 4 61 9 . 97 3 66 1 , 26 5 SM U D 12 , 96 4 , 80 0 75 9 , 91 3 28 5 , 05 8 73 9 , 01 6 01 1 . 09 2 87 5 . 93 1 63 3 54 7 04 9 , 97 4 03 3 , 81 6 86 4 16 6 23 1 58 1 18 0 , 98 1 1, 4 9 9 , 72 6 Sie r r a P a c i f i c I IP P L a y o f f 15 , 89 1 23 6 05 6 54 1 03 0 , 24 3 98 1 , 26 1 89 1 73 5 02 0 , 85 1 06 3 , 4 8 4 12 7 , 81 9 11 6 94 2 56 1 , 83 5 92 0 , 15 4 00 9 08 4 11 1 , 28 9 Pu g e t P o w a r 48 , 68 1 . 0 9 3 27 9 80 7 18 4 78 9 75 9 , 98 0 63 0 , 4 5 5 91 0 , 66 1 95 5 13 1 04 3 , 84 0 19 5 18 4 06 2 , 63 7 28 0 84 3 18 2 , 23 2 21 5 , 73 5 Sie r r a P a c i f i c 21 , 17 1 , 15 8 82 5 , 12 1 75 2 , 19 4 75 8 11 7 71 3 , 52 8 82 7 , 56 5 77 5 , 69 8 74 9 30 8 77 3 , 82 9 69 4 , 43 3 86 9 79 9 76 1 , 82 3 66 9 74 2 UM P A S a l e 38 7 , 4 4 4 19 8 12 4 18 0 29 6 19 4 , 20 0 18 7 , 13 1 18 8 , 65 0 19 7 82 9 22 2 , 25 6 19 9 , 07 4 20 3 , 75 8 20 3 , 50 5 20 1 , 69 0 20 0 , 93 1 Ne v a d a ( B a a e ) CD W R S a l a 64 7 , 34 2 62 7 90 6 62 0 16 0 68 8 , 38 9 62 2 , 22 9 66 1 , 20 0 61 3 , 32 0 62 0 , 16 0 62 7 , 00 0 59 3 , 70 6 65 9 71 2 61 2 , 96 1 70 0 , 59 8 WA P A 19 , 04 7 , 64 1 55 3 54 3 50 6 , 19 7 51 1 , 57 4 48 7 , 06 4 57 9 15 6 67 8 , 22 7 72 1 67 9 97 4 , 74 4 84 0 , 79 7 1,4 1 0 34 1 37 0 , 13 6 1,4 1 4 , 18 2 WA P A I I 38 0 , 15 2 20 2 , 30 0 13 3 , 30 5 95 2 , 91 4 92 3 , 49 5 68 9 , 60 0 57 7 , 06 4 22 5 , 13 6 20 2 , 30 0 16 7 , 81 2 11 7 , 64 2 07 0 , 87 8 11 7 , 70 6 PS C O 02 1 , 4 2 8 11 0 , 37 7 00 8 , 81 0 01 5 02 4 08 2 , 46 3 14 7 , 49 6 11 6 07 2 12 0 , 53 7 08 8 27 9 95 4 , 95 8 10 9 , 86 3 08 6 , 01 5 18 1 73 4 EW E B 9 5 Ra d d i n g S a l a 31 8 , 32 1 07 9 , 72 4 99 9 56 5 99 5 84 3 93 8 , 65 3 97 9 , 17 6 96 2 , 51 0 09 9 39 3 09 3 , 75 3 16 2 . 07 0 97 2 , 49 3 94 5 , 0 5 4 09 0 , 08 7 Cl a r k S a l e 81 4 , 32 3 89 7 , 89 2 52 0 61 4 08 8 , 34 4 37 7 , 91 9 83 9 , 69 3 02 3 , 41 7 66 8 , 90 1 67 9 , 74 1 24 7 , 47 8 87 7 , 4 7 2 71 3 , 10 6 90 1 , 74 5 Hin s o n 23 , 20 7 , 22 1 (2 1 , 33 7 ) 34 5 16 8 50 7 86 7 2, 4 2 3 , 59 7 70 6 , 38 4 66 9 , 70 2 55 4 , 50 4 21 , 33 7 Bla c k H i l l s C a p a c i t y 79 2 , 84 0 15 0 , 00 0 10 0 , 52 8 22 2 , 13 3 75 , 00 0 24 5 , 17 9 Bla c k H i l l s S t o r a g e 11 , 16 5 11 , 16 5 Sp r i n g f J e l d 73 9 75 7 79 5 57 6 94 5 90 6 00 4 , 81 3 89 0 94 0 57 9 52 3 34 2 , 01 2 48 9 95 5 27 1 , 71 0 06 5 , 98 9 95 0 07 3 57 3 , 45 0 82 9 , 63 1 ES I - Ka i s e r PN G C 43 3 , 4 2 1 41 1 09 7 32 0 , 25 7 41 1 09 7 08 5 76 0 53 9 , 37 9 1, 4 8 9 , 83 0 1,4 1 2 , 99 0 35 1 91 4 1,4 1 1 09 7 Ch e y e n n e S a l e 26 , 59 6 75 1 27 7 74 4 14 2 , 28 9 22 7 . 62 8 10 4 45 4 16 4 , 40 8 11 3 , 99 3 31 2 29 0 31 5 55 9 18 3 36 5 19 2 , 87 5 18 6 76 7 37 5 , 40 0 De s e r e t S u p p l e m a n l a l 32 , 17 7 , 61 3 35 2 , 69 0 51 0 . 45 8 31 5 , 71 2 82 4 71 7 68 0 01 3 53 1 , 88 6 09 9 96 4 52 3 , 64 9 82 3 , 14 8 46 8 64 4 66 4 98 1 , 06 8 Ok a n o g a n 66 1 , 07 5 19 4 , 51 2 16 9 98 7 14 5 , 87 5 11 8 , 73 7 89 8 74 , 29 6 12 7 95 5 11 2 , 61 4 13 3 , 73 4 14 3 , 50 2 16 3 , 45 2 19 4 . 51 2 UM P A I I S a l e 57 4 , 18 3 40 9 , 76 0 05 2 , 51 1 12 4 , 78 1 98 8 , 07 9 (9 4 8 ) Pla i n s E l a c ~ i c G & T Sp r i n g f i e l d I I 02 0 , 96 2 70 4 , 91 8 69 1 , 10 1 74 6 39 0 34 5 69 4 34 5 69 4 71 9 82 6 71 9 82 6 74 7 51 2 Co w l i l z - BH P 39 8 14 1 20 5 , 65 8 18 5 , 4 4 1 21 3 86 0 20 1 08 2 21 6 21 7 20 6 , 4 9 6 21 2 , 24 5 20 6 71 9 16 1 , 23 6 19 1 , 81 7 19 0 , 29 8 20 5 07 3 Cl a r k - 60 2 , 25 5 23 7 40 8 21 9 , 49 8 23 1 , 48 8 21 8 , 79 9 22 7 , 39 7 22 1 08 6 23 0 , 87 4 17 1 36 1 13 5 . 54 6 24 0 , 51 7 22 7 , 38 2 24 0 , 89 7 Cl a r k - 02 6 , 12 0 25 8 , 30 3 23 9 79 9 25 8 , 30 3 24 7 , 70 7 25 6 30 3 24 8 , 05 1 25 6 , 30 3 25 6 , 30 3 24 8 , 05 1 25 6 64 6 24 8 , 05 1 25 6 30 3 Hu r r i c a n e S a l e s 21 5 , 09 6 53 6 42 4 12 , 51 6 13 , 04 8 16 , 82 8 19 , 71 2 86 8 40 , 82 4 63 2 10 , 36 0 14 , 50 4 84 4 AP P A - AE P C O 88 7 , 60 9 55 5 73 6 38 6 , 4 0 5 1, 4 9 5 , 4 2 0 1,4 9 0 , 29 4 75 9 75 4 AP P A - ED # 2 94 3 , 07 3 10 6 , 74 5 11 0 21 8 28 1 , 42 4 40 4 93 6 40 4 , 26 9 40 3 , 95 1 12 5 , 31 2 10 6 , 21 6 AP P A - Me s a 53 6 , 57 5 51 1 65 1 50 5 , 94 6 50 1 , 38 1 51 1 , 65 1 50 5 , 94 6 Ci t i z e n s P o w e r 84 6 , 4 5 8 38 1 , 81 3 42 9 54 0 34 1 . 10 5 43 1 , 82 1 46 8 , 14 5 37 8 65 5 38 9 92 0 26 9 , 17 8 26 4 50 6 23 6 63 3 48 4 . 28 5 54 8 85 6 Gr e a n M o u n l a i n s 23 , 96 1 , 81 7 65 1 11 4 34 8 , 86 8 24 6 . 39 7 50 1 , 56 6 24 4 , 56 4 23 4 , 99 0 21 0 , 53 6 81 9 , 65 9 70 2 , 34 5 1, 4 8 0 79 8 61 6 , 96 9 92 4 , 01 1 Fla t h a a d S a l a 66 4 , 88 8 24 2 , 10 6 16 1 97 2 24 2 , 10 8 20 0 , 37 0 24 2 , 10 6 20 2 04 0 24 2 , 10 8 24 2 , 10 8 20 2 04 0 24 3 77 8 20 2 04 0 24 2 , 10 8 BP A W i n d S a l e 72 6 , 09 1 34 9 , 97 6 30 3 , 75 6 23 6 17 8 20 9 , 56 0 21 3 , 66 1 16 3 00 6 10 7 85 9 14 8 , 94 5 21 0 , 68 0 25 3 , 28 1 21 5 , 4 3 8 29 3 , 75 2 SD G & E S a l e 30 , 26 6 , 99 4 56 3 , 59 8 39 8 20 4 56 3 , 59 8 47 7 , 4 5 5 56 3 59 8 2,4 8 0 , 90 1 56 3 , 59 8 56 3 , 59 8 2, 4 8 0 , 90 1 56 7 , 04 4 48 0 , 90 1 56 3 59 8 Sh o r l T e r m F i r m S a l s e P 26 2 00 3 , 32 3 37 4 24 4 8,4 8 9 94 0 13 , 36 2 , 49 7 75 3 , 4 2 4 11 , 94 1 97 7 05 8 , 59 7 24 , 29 0 02 0 46 , 74 0 , 61 8 66 , 31 9 , 22 4 14 , 84 1 39 6 16 , 35 9 , 52 1 12 , 47 1 , 86 6 Sh o r t T e r m F i r m S a l a s l n t e r t i a 19 9 95 6 , 89 1 00 5 07 0 95 8 62 7 97 2 , 08 6 67 7 80 1 43 5 55 9 29 , 73 6 , 97 1 25 , 55 2 , 78 3 46 , 37 4 , 00 3 38 , 19 2 , 19 5 15 , 67 0 32 4 13 , 58 1 , 18 6 80 0 , 28 5 Sh o r l T e r m S a l e s U 29 4 , 32 5 , 62 9 15 , 33 7 , 02 4 15 , 17 1 , 00 5 18 , 04 6 , 13 9 79 7 21 1 16 8 , 86 6 29 , 4 1 4 , 32 6 41 , 98 6 21 2 60 , 14 5 , 52 7 28 , 02 9 , 85 5 21 , 4 8 3 , 53 5 17 , 58 2 , 24 3 16 . 18 3 , 68 6 Se c o n d a r y S a l e s 53 7 , 01 3 (6 , 85 3 ) (1 3 4 78 8 ) (1 , 99 4 , 10 7 ) (9 1 4 77 4 ) 12 0 48 7 24 , 4 0 7 , 64 4 88 9 , 05 0 14 , 09 4 , 4 5 3 44 , 59 5 31 , 30 8 Sy s t e m S a l e s P P L Sy s t e m S a l e s U P L -- - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - -- - - - - - - - - -- - - -- - - - - - - - - -- - - - - -- - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - - -- - - - - -- - - - TO T A L S P E C I A L S A L E S 39 1 . 79 6 . 99 3 29 7 24 1 75 . 13 5 . 87 9 83 8 . 40 3 70 . 14 5 59 1 94 . 34 5 47 5 15 7 . 14 3 . 94 3 15 8 59 0 . 95 9 21 7 . 81 9 44 5 18 0 . 99 5 . 21 8 10 2 . 35 3 . 58 7 38 5 . 27 8 82 . 9 4 5 . 97 4 PU R C H A S E D P O W E R & N E T I N T E R C H A N G E BP A P e a k P u r c h a s e 62 , 16 0 , 00 0 18 0 , 00 0 18 0 00 0 18 0 , 00 0 18 0 00 0 18 0 00 0 18 0 , 00 0 18 0 , 00 0 18 0 , 00 0 18 0 00 0 18 0 00 0 18 0 00 0 18 0 , 00 0 BP A S u p p l e m e n t a l 26 , 12 4 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 BP A E n t i t l e m e n t 26 , 12 4 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 17 7 Bla c k H i l l s C a p a c i t y 78 2 , 16 3 18 7 , 10 5 10 6 , 18 3 82 , 82 5 97 , 32 7 14 1 59 7 17 4 , 48 0 28 2 39 9 39 9 11 9 81 2 18 9 , 86 7 17 0 , 08 8 16 2 08 1 Co G e n / J a m e a R i v e r 16 , 89 2 , 28 6 88 0 , 70 7 51 7 71 7 40 4 , 68 2 1, 4 1 4 , 55 0 13 3 , 13 0 1,4 4 1 36 9 49 9 , 70 2 38 2 , 89 9 22 0 49 5 14 5 , 68 1 50 0 19 9 57 1 , 17 5 Mid C o l u m b i a 17 , 58 7 , 89 3 33 8 , 89 1 28 2 , 74 2 30 8 , 35 0 1, 4 3 3 69 5 63 2 25 3 36 7 , 51 7 36 7 , 15 1 35 0 , 79 6 66 4 . 52 4 10 5 92 5 28 7 89 5 44 8 15 4 Gra n t C o u n t y 06 6 , 00 0 22 3 , 79 0 17 4 , 65 0 20 3 63 0 25 9 , 31 5 32 7 , 02 0 34 9 , 81 0 35 9 , 73 0 33 4 , 56 5 24 8 , 36 0 20 6 50 0 16 5 , 48 0 21 3 , 15 0 PG E C o v e 23 1 71 8 18 , 96 1 14 7 23 , 96 1 96 1 18 , 96 1 18 , 96 1 18 , 96 1 96 1 96 1 18 , 96 1 18 , 96 1 96 1 US S R G r e e n s p r i n g a 98 7 , 89 5 80 , 77 6 82 , 30 8 56 4 15 4 20 6 84 , 58 0 74 , 17 5 10 0 , 11 1 82 , 37 2 67 1 82 2 15 6 F. C o n ~ a c l 8 - P P & L 50 , 88 6 10 8 34 8 , 20 9 90 2 52 0 59 5 , 49 4 64 0 , 97 1 55 0 45 7 23 7 , 71 0 98 1 , 01 3 64 2 , 87 7 28 7 , 48 1 71 8 57 0 80 8 05 6 19 2 , 95 0 Tr i S l a t e P u r c h a s e 10 , 53 9 . 90 3 00 0 , 84 4 99 3 57 9 98 0 , 97 5 95 6 . 93 2 96 0 , 11 9 64 4 , 09 2 82 7 , 97 7 88 2 . 26 1 29 2 , 79 3 92 6 , 4 3 2 90 0 , 56 0 97 3 , 33 8 So u t h I d a h o / S t o r a g e (3 2 8 , 74 0 ) (1 3 35 2 ) (1 4 , 76 6 ) 47 , 83 9 97 , 17 7 48 , 07 4 49 0 96 8 ) 01 0 (8 5 , 99 3 ) (4 1 0 , 25 1 ) AP S S u p p l e m s n l a l 86 9 , 01 4 25 , 55 9 29 3 14 9 , 45 8 (1 4 3 63 8 ) 45 0 53 4 18 7 , 09 4 19 8 , 71 4 Tr i S l a l e E x c h a n g e (3 , 56 1 61 2 ) (4 6 6 , 4 3 8 ) (4 6 6 , 4 3 8 ) (4 6 8 , 4 3 8 ) (4 8 8 , 4 3 8 ) (4 6 6 , 4 3 8 ) (4 6 6 , 4 3 8 ) (4 6 6 , 43 8 ) (4 6 6 , 4 3 8 ) (4 8 8 , 4 3 8 ) 28 4 , 35 0 16 1 , 39 2 19 0 , 58 6 SC E P u r c h a s e 13 , 76 6 , 76 3 92 3 . 60 3 60 1 , 89 4 (1 9 9 05 3 ) 49 2 . 40 1 83 0 , 01 9 11 7 89 9 Av i s l a S u m m e r P u r c h a s e 67 2 , 48 1 90 3 80 5 18 3 , 41 0 52 4 , 35 0 06 0 , 91 6 Av i s l a E x c h a n g e 30 2 , 50 0 (9 9 00 0 ) (1 0 1 05 0 ) 37 2 , 30 0 62 7 , 30 0 16 1 , 4 0 0 44 8 , 80 0 (1 0 7 . 25 0 ) Ge m S t a t a 30 2 . 19 5 19 6 , 10 0 20 0 , 80 0 19 6 20 0 19 6 , 20 0 19 6 20 0 19 6 , 20 0 20 1 50 0 19 6 , 20 0 22 8 , 60 0 99 5 19 9 , 4 0 0 19 7 , 80 0 GS L M 42 6 , 31 6 81 , 62 0 31 2 82 , 4 6 9 38 , 35 4 49 , 36 9 81 8 77 . 37 4 aF C o n ~ a c l 8 - U P & L 26 , 59 6 , 08 8 22 5 69 5 15 4 46 2 26 3 60 2 92 9 53 5 16 0 , 00 4 27 3 , 68 9 43 9 , 87 5 45 3 , 64 8 29 8 , 0 1 1 09 1 02 1 19 2 31 8 11 4 , 22 8 IP P L a y o f f 15 , 89 1 , 23 6 05 6 , 54 1 03 0 , 24 3 98 1 26 1 89 1 73 5 02 0 , 85 1 06 3 , 4 8 4 12 7 , 81 9 11 6 , 94 2 56 1 , 83 5 92 0 15 4 00 9 08 4 11 1 , 28 9 Bla c k H i l l s P u r c h a s e 9 6 10 , 34 8 , 51 8 11 7 , 79 2 58 , 36 6 17 6 , 46 3 29 6 34 5 42 0 77 6 31 4 84 7 1, 4 1 9 , 76 5 97 3 31 2 11 9 44 1 16 2 , 73 5 15 5 91 8 13 2 , 75 8 Re d d i n g P u r c h a s e 72 6 , 85 3 23 7 64 0 15 9 , 62 8 22 7 , 17 2 18 4 , 27 2 20 2 , 87 1 29 0 , 57 4 29 5 37 1 46 2 60 7 22 6 , 99 9 93 9 18 8 . 15 4 20 7 , 4 2 5 Po w e r P l a n n i n g 0 2 1 2 0 1 2 0 0 2 pa g e 1 Att a c h I I P A D R 1 , 15 a . xl s He r m i s l o n P u r c h a . e 91 5 , 59 0 69 9 05 5 81 9 04 1 59 3 . 00 0 95 8 , 03 8 92 7 61 4 13 1 96 9 28 5 03 9 27 4 56 3 18 5 , 00 0 19 3 60 5 74 5 58 5 10 3 , 08 1 De . e r e l A n n u a l P u r c h a . e De . e r e l M o n t h l y P u r c h a . e De . e r e l E x p a n . i o n P u r c h a . e 44 1 . 33 6 86 6 16 6 84 8 10 7 , 81 4 79 3 17 1 33 7 11 4 , 92 7 14 4 , 00 0 87 , 83 4 12 1 , 83 1 18 0 48 5 22 5 53 9 (3 , 53 8 ) De s e r e l N o n - Fi' m P u r c h a . e 98 7 , 17 3 (7 4 , 77 8 ) 27 8 24 8 52 7 75 9 19 8 , 59 2 (3 3 60 4 ) 71 9 15 2 10 3 81 7 07 8 56 8 33 6 10 9 40 6 24 6 82 , 60 2 38 4 , 46 1 Hu r r i c a n e P u r c h a . e 54 4 3. 4 5 2 00 1 32 3 78 3 68 2 68 2 12 0 20 1 28 1 00 4 21 7 41 8 L T F R e . e r v e P u r c h a s e s 23 3 50 0 19 9 00 0 19 9 , 00 0 50 0 28 9 , 34 5 17 4 50 0 17 4 50 0 15 9 65 5 17 4 , 50 0 19 9 00 0 19 9 00 0 19 9 00 0 20 8 50 0 Tr a n . A l t a P u r c h a . e 41 0 85 2 50 0 87 1 98 8 , 34 8 50 0 87 1 49 8 , 32 8 84 8 27 0 29 4 53 4 58 7 , 49 2 10 , 58 7 , 49 2 10 , 09 3 78 9 67 0 31 8 39 0 82 8 87 0 31 8 Sh o r l T e r m F i ' m P u r c h P P L 81 8 70 2 , 52 8 17 , 58 4 38 1 54 8 , 99 2 30 9 55 0 80 6 07 4 58 4 71 0 33 8 16 9 87 , 01 3 , 71 9 14 5 28 0 , 21 8 12 8 , 18 2 , 39 5 36 , 01 7 30 7 39 , 25 3 97 4 26 , 82 3 03 9 Sh o r l T e r m F i ' m P u r c h U P L 29 0 92 0 , 55 4 92 0 71 9 66 0 13 4 12 , 15 7 25 8 10 , 00 5 66 0 20 , 96 7 73 1 80 , 13 4 42 8 65 , 63 5 95 4 06 7 . 89 4 21 , 95 5 , 04 0 12 , 88 0 , 40 0 35 5 40 0 20 0 , 13 8 Se c o n d a r y P u r c h a . e . 13 0 89 5 , 55 5 75 0 , 00 0 72 7 21 3 02 7 54 8 50 1 , 26 8 66 9 30 9 68 1 16 2 12 , 76 2 02 1 13 , 89 0 07 7 58 8 , 83 9 10 , 87 5 81 8 96 0 99 7 28 1 30 9 Sy e l e m P u r c h a s e P P L Sy s t a m P u r c h e . e U P L -- - - - - - - - - - - -- - - - -- - - - - -- -- - - -- - - - - - - - - - - - -- - - - - - - -- - - - - - - -- - - - - - -- - - - TO T A L P U R C H A S E D P W & N E T I N T . 48 2 , 5 3 5 25 8 89 8 49 7 59 , 34 1 49 1 49 5 24 9 52 , 4 5 2 , 4 3 4 94 , 82 2 . 8 4 0 j7 8 27 0 12 8 20 8 80 5 27 5 28 2 99 4 11 8 22 0 44 0 32 4 97 , 05 2 , 73 8 92 . 0 3 8 , 46 7 12 3 90 1 TO T A L W H E E U N G & U , O F F . E X P E N 75 , 86 9 45 6 69 2 . 8 3 7 51 8 87 7 52 2 , 4 1 5 07 4 73 2 71 4 86 5 29 4 78 2 88 2 83 1 15 5 03 4 49 0 29 9 37 6 05 1 , 03 5 85 2 , 24 0 TH E R M A L F U E L B U R N E X P E N S E Ce n l r a l i a Da v e J o h n a l o n (8 4 6 41 8 ) 88 3 53 7 80 1 31 8 18 2 , 09 4 80 1 31 8 51 7 40 4 80 1 , 31 8 00 5 51 8 50 5 27 4 85 1 85 1 51 7 40 4 80 1 31 8 51 7 , 40 4 80 1 31 8 Ji m B r i d g e r (2 7 8 85 8 ) 74 9 58 5 41 1 81 4 88 9 11 8 41 1 , 81 4 14 0 48 5 41 1 , 81 4 07 4 01 0 84 5 13 2 41 1 81 4 15 5 45 0 41 1 81 4 39 4 52 9 41 1 81 4 Wy o d e k (5 9 19 7 ) 87 3 42 5 78 4 98 3 88 9 60 4 78 4 98 3 72 7 38 4 78 4 98 3 32 8 72 7 78 4 98 3 78 4 98 3 72 7 38 4 78 4 98 3 72 7 38 4 78 4 98 3 Co l s l r i p 12 9 , 29 9 85 7 89 8 81 5 45 1 85 7 89 8 83 8 , 87 4 85 7 , 89 8 33 4 , 11 8 32 7 88 0 85 2 , 57 0 83 8 67 4 65 7 , 89 8 83 6 67 4 85 7 89 6 He r m i a l o n 94 5 93 7 57 8 77 3 39 0 80 0 57 8 , 77 3 48 4 88 6 84 9 , 80 3 77 9 03 9 57 8 77 3 57 8 , 77 3 48 4 88 6 57 8 , 77 3 48 4 88 6 57 8 77 3 Ca r b o n 44 8 08 2 78 2 12 4 71 2 , 95 5 78 2 , 12 4 73 7 54 0 51 4 , 09 4 73 7 54 0 78 2 , 12 4 78 2 , 12 4 43 3 84 8 78 2 12 4 73 7 54 0 78 2 12 4 Na u g h l o n (1 4 3 , 42 4 ) 24 0 , 39 1 65 5 35 2 86 5 20 1 14 0 , 54 8 02 2 , 88 8 22 8 22 8 45 9 51 4 20 0 , 73 2 20 0 73 2 03 2 , 98 7 20 0 73 2 03 2 , 98 7 20 0 73 2 Hu n t i n g l o n 84 8 32 0 73 4 8& 4 49 3 90 5 73 4 , 88 4 81 4 38 5 10 1 , 10 1 81 4 38 5 73 4 88 4 73 4 , 88 4 81 4 38 5 92 1 , 45 4 81 4 38 5 73 4 , 88 4 Hu n l e r 55 , 84 3 24 5 12 8 48 4 08 5 24 2 12 8 . 4 8 4 98 1 O9 4 03 7 , 45 7 89 4 12 8 12 8 48 4 12 8 , 48 4 14 5 44 8 12 8 48 4 98 1 09 4 12 8 , 48 4 Blu n d e l l 03 9 12 9 35 4 , 98 2 33 2 , 08 2 35 4 98 2 34 3 , 51 2 35 4 98 2 19 1 79 4 35 4 98 2 35 4 , 96 2 34 3 , 51 2 35 4 98 2 34 3 , 51 2 35 4 98 2 Ch o l l a 34 8 40 4 04 7 , 05 7 78 5 95 7 54 1 47 7 03 8 18 3 91 8 50 7 04 7 , 05 7 04 7 05 7 91 8 , 50 7 04 7 , 05 7 91 8 50 7 04 7 , 05 7 Cr a i g 13 , 80 9 99 2 20 7 88 3 12 9 78 8 20 7 68 3 73 5 36 8 99 2 58 3 16 8 , 72 5 20 7 88 3 20 7 88 3 16 8 72 5 20 7 88 3 18 8 72 5 20 7 88 3 Ha y d e n 88 8 81 0 54 5 10 6 50 9 93 8 54 5 , 10 6 52 7 52 2 23 3 13 4 29 5 , 83 9 54 5 10 6 54 5 10 8 30 2 , 22 2 54 5 10 8 52 7 , 52 2 54 5 10 6 Ga d e b y 82 9 21 6 84 1 85 1 80 0 44 1 84 1 , 63 9 61 7 07 2 83 8 42 5 86 5 84 1 02 7 82 9 02 7 82 9 88 5 84 1 84 1 , 85 1 62 1 14 6 84 1 85 1 In c r e m e n t a l C o a l D i s c o u n l f (4 7 9 , 27 9 ) Wy o d a k Na u g h l o n Ji m B r i d g e r -- - - - - - - - - - - - - -- - - - -- - -- - - - -- - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - -- - - - -- - - - - - - -- - - TO T A L F U E L B U R N E X P E N S E 44 2 , 0 5 3 15 2 38 , 11 0 22 7 22 2 , 53 4 34 , 54 8 15 3 80 7 , 27 0 32 , 4 3 9 74 0 86 3 , 28 4 40 , 84 8 82 4 42 , 0 8 8 79 3 34 4 85 0 38 , 84 2 19 7 88 4 07 4 65 5 80 7 =- - = - - = = == = = -- = -- - - - - NE T P O W E R C O S T 58 8 48 0 , 87 2 40 4 31 9 94 7 , 02 3 92 7 41 3 22 , 98 8 84 4 63 1 , 57 0 59 , 08 4 24 1 84 5 , 80 2 93 , 09 2 82 1 82 4 , 24 5 84 0 72 2 38 8 , 29 8 86 5 , 77 4 -- - - - -= = - - - =- - - - -- - - -- - - - =- ~ = -- - - - - Na t P o w e r Co s t / N a t S y s t a m Lo a d 11 . 13 . 4 9 19 . 19 . 20 . Po w e r P l a n n i n g 0 2 1 2 0 1 2 0 0 2 pa g e 2 At t a c h I I P A D R 1 . 15 8 . xl8 Pa c i f t C o r p Ty p a l / , U t s h Ne t P - . . . C o e I E.. . . g y A. a t y . 12 - Mo n t h E n d i n g 0 9 1 3 0 1 0 0 (M W H ) To t a l Ja n Fe b Ma r Ap r Ma y Ju n Ju l Au g Sa p Oc t No v De c NE T S Y S T E M L O A D 52 , 8 7 8 91 8 73 8 , 72 4 31 3 , 13 8 28 5 , 75 3 98 7 , 39 9 18 5 , 89 8 38 1 , 27 8 79 8 97 1 78 0 , 03 8 11 3 87 2 09 8 28 9 40 0 , 92 7 85 2 . 8 3 3 SP E C I A L S A L E S F O R R E S A L E Bla c k H i l l s 50 1 15 9 42 , 70 6 24 8 34 4 46 3 53 6 98 5 80 0 35 1 02 2 72 0 32 0 41 , 66 4 So C a l E d i s o n ( P ) 62 1 83 3 58 , 50 9 48 , 27 3 73 7 40 , 24 8 28 0 45 , 80 8 55 , 89 3 59 , 02 4 54 , 68 3 58 , 78 3 57 , 56 4 03 4 So C a l E d i s o n ( U ) 62 1 83 3 58 , 50 9 48 , 27 3 41 , 73 7 24 8 28 0 80 8 89 3 02 4 68 3 58 , 78 3 56 4 03 4 SM U D 35 0 , 40 0 53 8 70 4 97 3 27 , 32 7 23 , 67 4 17 , 12 3 28 , 37 8 94 1 72 , 00 4 28 6 31 , 91 8 40 , 53 3 Sie r r a P a c i f I C I IP P L a y o f f 42 6 59 9 37 6 23 4 12 , 24 1 20 , 70 9 21 , 97 5 23 , 70 9 48 , 64 1 96 7 91 1 86 3 82 4 46 , 95 1 Pu g e t P o w e r I I 09 4 21 5 10 4 10 0 97 . 4 4 0 74 . 0 0 0 66 , 50 0 82 , 72 5 85 , 30 0 90 . 4 2 5 99 , 20 0 52 5 10 4 18 0 45 0 10 0 39 0 Sie r r a P a c i f i c I I 45 9 . 4 9 5 05 0 43 5 94 0 34 , 52 1 96 5 22 5 37 , 26 5 39 , 14 4 06 0 49 8 22 4 16 8 UM P A S a l a 42 , 62 9 51 3 14 2 32 7 99 2 06 4 3,4 9 9 65 8 55 8 78 0 76 8 68 2 64 6 Ne v a d a ( B a s e ) CD W R 80 7 , 08 1 05 3 60 0 53 , 59 0 49 , 72 1 86 8 20 0 60 0 00 0 05 3 51 , 91 3 17 9 30 4 WA P A 52 4 81 8 85 9 57 3 43 , 85 9 43 , 71 0 44 , 64 0 43 , 17 5 66 2 43 , 92 0 43 , 20 0 91 8 42 . 4 4 4 43 , 85 9 WA P A I I 59 7 , 27 1 55 , 80 6 19 9 42 , 78 4 40 0 60 0 20 0 57 , 00 0 80 0 54 , 00 0 55 , 79 6 52 , 88 6 80 0 PS C O 15 9 , 57 2 23 8 78 4 17 2 46 2 10 0 , 59 9 98 , 60 0 98 , 88 4 96 , 83 2 35 1 98 , 20 5 98 , 68 8 10 2 , EW E B 9 5 Re d d i n g S e l e 37 3 , 09 1 20 5 52 0 25 6 20 0 28 , 07 4 26 , 89 2 36 , 60 0 36 , 20 0 36 , 95 0 60 0 65 4 35 , 94 0 Cla r k S a l e 43 3 01 3 16 9 , 26 0 15 8 , 34 0 14 5 08 0 73 7 11 1 22 8 50 0 48 . 4 5 2 26 8 60 0 16 9 , 48 8 16 3 , 80 0 16 9 26 0 Hi n s o n 66 7 , 82 6 (6 1 4 ) 15 3 81 6 16 8 74 3 10 4 16 3 , 15 5 15 9 , 84 0 61 4 Bl a c k H i l l s C a p a c i t y 38 0 32 0 93 5 12 5 Bla c k H i l l s S t o r a g e 01 5 01 5 Sp r i n g f i e l d 23 9 11 5 34 2 87 0 50 5 01 7 17 , 42 5 9.4 2 8 61 8 88 0 24 , 12 5 03 7 59 3 20 , 27 5 ES I . Ka i s e r PN G C 36 0 52 0 40 , 92 0 38 , 28 0 40 , 92 0 46 5 64 0 20 0 97 5 39 , 20 0 40 , 92 0 Ch e y e n n e S a l e 96 3 , 15 7 71 1 20 4 77 0 22 4 79 , 96 5 12 3 83 , 43 5 84 , 25 4 65 9 31 3 92 9 57 0 De s e r e t S u p p l e m e n t a l 47 3 00 8 88 6 79 3 57 0 29 4 10 8 , 25 0 99 0 42 , 06 4 30 4 87 6 61 5 99 4 35 2 Ok a n o g a n 48 , 29 2 65 5 94 2 24 1 3. 4 5 2 38 1 16 0 72 0 27 4 88 8 17 2 75 2 65 5 UM P A I I S a l e 13 6 48 9 94 3 14 3 62 9 36 , 82 2 (4 8 ) Pl a i n s E l e c t r i c G & T Sp r i n 9 f i e l d I I 14 5 20 0 40 0 00 0 60 0 10 , 00 0 00 0 80 0 80 0 60 0 Co w l i l z . BH P 69 . 4 3 5 96 0 37 3 19 8 82 7 26 6 98 4 15 1 99 1 67 0 55 8 51 4 94 3 Cl a r k - 50 5 88 9 36 8 71 8 34 8 59 8 41 5 70 0 98 8 93 2 98 0 59 8 99 1 Cla r k - 87 , 64 0 44 0 96 0 44 0 19 0 44 0 20 0 44 0 7. 4 4 0 20 0 7. 4 5 0 20 0 44 0 Hu r r i c a n e S a l e 68 2 41 2 40 8 44 7 46 6 60 1 70 4 78 1 45 8 09 4 37 0 51 8 42 3 AP P A - AE P C O 11 4 14 6 89 0 75 0 47 1 31 , 15 5 88 0 AP P A . ED N 2 19 3 99 8 19 5 82 1 75 6 71 8 70 0 03 7 96 8 AP P A - Me s a 41 , 96 4 64 0 32 0 8,0 6 4 64 0 32 0 Ci t i z e n s P o w e r 13 2 , 42 9 10 , 88 0 24 0 72 0 30 5 13 , 91 0 79 0 12 0 68 0 54 4 80 0 13 , 80 0 64 0 Gr e e n M o u n t a i n s 18 3 , 50 2 16 , 84 7 07 8 00 5 13 , 17 7 51 7 12 , 76 0 70 6 32 , 66 7 14 , 63 1 10 , 08 2 13 , 10 9 92 3 Fla t h e a d S a l e 61 4 , 88 0 52 , 08 0 72 0 52 , 08 0 33 0 52 , 08 0 40 0 52 , 08 0 52 , 08 0 50 , 40 0 52 , 15 0 50 . 4 0 0 08 0 BP A W i n d S a l e 78 9 56 8 85 0 77 1 34 6 01 1 57 9 52 0 09 9 96 9 33 7 68 9 03 0 SD G & E S a l e 87 8 40 0 40 0 69 , 80 0 40 0 90 0 74 , 40 0 72 , 00 0 74 , 40 0 40 0 00 0 50 0 00 0 74 . 4 0 0 Sh o r t T e r m F i r m S a l s e P 78 1 64 9 27 5 , 87 8 28 9 . 74 8 50 3 83 8 40 8 , 5 2 8 37 4 40 2 37 0 58 0 28 9 69 5 35 1 87 9 80 7 33 0 39 3 , 57 8 46 5 04 8 45 3 38 9 Sh o r t T e r m F i r m S a l e s I n t a r l i e 37 8 , 77 4 12 3 48 7 89 9 12 2 85 2 15 5 , 27 8 15 1 38 0 16 4 20 8 13 4 02 4 21 5 , 4 0 8 22 0 48 4 38 1 , 31 4 38 8 , 63 5 23 1 82 5 Sh o r t T e r m S a l e s U 27 3 , 58 9 55 8 42 2 56 4 72 3 83 8 08 6 45 7 29 1 39 2 , 78 8 54 5 11 9 35 2 43 7 50 9 . 4 2 7 38 5 72 2 67 1 , 39 5 60 8 , 64 2 59 1 55 9 Sa c o n d a r y S a l e s 91 0 . 4 0 1 66 5 34 1 57 3 82 5 23 5 31 8 27 4 47 3 24 4 47 8 10 3 84 0 70 0 18 7 Sy s t e m S a l e s P P L Sy s t e m S a l e s U P L -- - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - -- - - - - - - -- - - - - - -- - - - - - - - - - - - - - - - - -- - - - -- - - - - - - -- - - - - TO T A L S P E C I A L S A L E S 48 0 20 9 2, 1 8 8 74 8 22 1 95 8 2,3 8 5 11 5 2, 0 5 8 24 4 2, 2 7 8 6V 2 2,3 7 0 , 02 0 13 5 07 0 2,3 5 8 04 1 42 5 72 9 79 4 , 98 0 77 1 , 45 8 49 4 15 8 -- - - - --- - - - - - - -= = = = - - - - -- - " = -- = -- - - - -- - -- - =-- = = - ~ = -- = -- - TO T A L R E Q U I R E M E N T S 35 7 12 5 92 7 , 47 2 53 5 09 4 85 0 86 8 04 5 , 64 3 44 2 , 3 8 8 75 1 29 8 93 4 , 04 1 11 8 , 07 7 53 8 , 80 1 89 3 , 28 9 17 2 , 3 8 5 34 8 , 98 9 == = =- - == = = = = = == = = = = = -- - - - -- - -- = = -- - - == = = = = - - = = = = = = = = - ~ = = = = = = = -- - - == -- - - - - = - - - - - PU R C H A S E D P O W E R & N E T I N T E R C H A N G E BP A S u p p l e m e n t a l (8 0 ) (1 9 6 ) 14 4 (6 4 ) (8 5 ) Bla c k H i l l a C a p a c i t y 13 7 76 1 29 4 35 5 86 6 38 7 66 1 78 1 Co G a n / J a m e s R i v e r 37 4 13 7 78 2 33 , 81 5 11 1 33 0 25 , 09 7 92 4 21 8 30 , 62 9 27 , 03 2 37 5 33 , 22 7 34 . 79 9 Mid C o l u m b i a 92 1 , 22 4 21 1 , 70 8 19 8 71 3 18 0 , 53 0 11 8 , 59 0 15 8 , 64 5 16 6 , 53 9 18 8 90 9 14 8 , 98 1 13 5 27 3 18 0 , 48 2 12 9 51 1 18 7 38 3 Ca n a d i a n E n t i t l e m e n t (7 6 , 89 7 ) (8 . 4 1 1 ) 10 9 ) (8 , 58 8 ) 09 7 ) (8 . 50 2 ) 27 1 ) 33 4 ) 50 2 ) 27 7 ) 52 5 ) (6 , 45 3 ) (6 , 62 8 ) CS P E 85 , 59 7 09 6 57 5 88 3 39 5 61 7 40 4 78 5 78 5 6.4 0 4 89 2 66 1 09 8 Co l o c k u m (1 7 7 51 5 ) (2 0 , 64 5 ) (2 3 59 4 ) (1 9 86 8 ) 22 2 ) (3 , 11 9 ) (7 , 93 1 ) 64 8 ) (2 4 , 68 8 ) (1 8 , 03 6 ) (2 5 97 5 ) (1 2 , 10 1 ) (1 1 , 89 0 ) Gr a n l C o u n t y 87 , 60 0 39 4 99 0 61 8 40 9 34 2 99 6 27 8 55 9 09 6 90 0 72 8 09 0 PG E C o v e 24 , 08 4 02 8 93 2 02 8 97 8 02 8 98 0 06 4 02 8 98 0 03 0 98 0 02 8 IP C R e t u r n (9 0 10 6 ) 79 9 ) 47 7 ) (8 , 35 2 ) 93 5 ) (1 1 , 01 5 ) (1 1 , 14 4 ) 16 8 ) 27 2 ) (5 , 03 7 ) 06 0 ) (4 , 72 2 ) 12 5 ) US B R G r e e n s p r i n g s 72 , 84 0 50 4 45 4 59 4 52 8 15 2 55 7 02 0 10 1 97 6 82 8 09 3 03 3 F. C o n t r a c l s - P P & L 50 5 , 19 9 47 , 22 3 52 , 65 9 07 6 98 3 01 2 34 , 88 8 41 , 67 0 38 , 19 3 43 , 69 4 79 5 55 7 47 , 44 9 Tr i S t a t e P u r c h a s e 32 4 , 03 3 32 , 06 7 81 8 83 9 29 , 35 3 55 0 22 , 37 9 38 3 24 , 73 8 18 , 40 2 27 . 4 6 8 25 , 86 9 36 7 So u l h l d a h o (2 6 , 00 5 ) (4 ) 20 3 ) 36 0 ) 89 0 10 , 85 3 66 9 58 3 (5 4 3 ) 28 3 47 9 ) (3 5 67 4 ) AP S S u p p l e m e n t a l 10 3 43 0 40 0 15 0 5,4 5 3 (5 , 15 3 ) 77 5 74 , 80 5 19 , 00 0 Tr i S t a t e E x c h a n g e (3 2 , 92 4 ) 74 7 53 8 21 , 19 4 (2 4 87 5 ) (2 5 22 5 ) (2 5 98 0 ) (2 6 , 04 0 ) (2 6 04 0 ) (2 5 , 09 1 ) 85 0 14 , 67 2 32 6 SC E P u r c h a s e 39 , 34 5 69 0 14 , 09 8 25 9 30 0 Po w e r P l a n n i n g 0 2 1 2 0 1 2 0 0 2 pa g e 3 At l a c h I I P A D R 1 . 15 a . xls Re d d i n g E x c h a n g e Tr a n l A I i a P u r c h a l a 91 , 26 9 96 1 70 3 , 32 7 15 1 39 2 70 3 , 32 7 66 4 05 4 61 9 52 2 50 7 , 91 5 95 6 19 6 95 6 19 6 63 6 . 96 4 81 7 , 16 4 53 2 , 74 0 81 7 16 4 l T F R l l e r v e P u r c h a l e l 44 5 , 00 0 20 6 . 50 0 20 6 50 0 19 9 . 00 0 19 9 . 00 0 19 9 . 00 0 19 9 , 00 0 19 9 00 0 19 9 , 00 0 20 9 . 50 0 20 9 , 50 0 20 9 , 50 0 20 9 , 50 0 En r o n P u r c h a . . 11 2 , 80 0 43 1 , 60 0 39 8 , 40 0 44 8 20 0 43 1 60 0 43 1 , 60 0 43 1 , 60 0 43 1 , 60 0 44 8 , 20 0 39 8 , 4 0 0 44 8 , 20 0 39 8 , 40 0 41 5 00 0 ST F P u r c h a l e l P P l 44 1 , 03 2 , 45 2 53 . 34 9 . 84 4 49 . 64 6 . 27 2 52 . 64 2 02 1 31 , 22 3 . 29 2 18 , 55 8 , 87 2 13 , 69 1 , 93 7 33 , 13 0 . 0 3 8 39 , 38 7 , 03 5 44 . 20 2 . 68 7 23 , 65 4 , 08 7 30 : 9 2 4 , 81 7 50 . 62 1 , 55 0 ST F P u r c h a l e l U P l 50 0 , 4 7 5 , 26 1 41 . 4 5 1 . 11 7 44 , 38 4 . 32 6 42 . 29 5 82 1 58 . 81 8 . 87 3 28 . 20 5 86 4 43 , 75 2 , 68 3 60 , 66 2 , 58 0 55 , 66 0 86 1 46 , 30 3 , 22 6 27 , 52 4 , 69 1 21 . 45 0 . 64 1 31 , 96 4 . 57 6 Se c o n d a r y P u r c h a l e l 74 , 66 6 26 6 32 7 . 27 5 79 9 66 1 25 5 . 17 5 40 6 29 3 81 0 . 94 6 80 0 69 7 65 1 . 98 4 15 , 36 7 22 9 67 5 , 71 9 4,4 6 5 92 7 03 3 11 3 5, 0 7 2 . 04 7 -- - - -- - -- - - - - - TO T A L P U R C H A S E D P W & N E T I N T . 1, 4 5 2 , 84 7 55 2 13 8 , 02 7 , 58 7 13 3 . 90 4 . 74 4 13 7 53 3 , 49 6 12 1 , 94 9 . 99 9 83 , 68 6 , 4 6 3 98 , 65 2 . 05 6 14 3 . 38 4 . 71 6 14 9 66 4 61 6 13 3 65 0 , 67 0 91 . 13 4 66 5 95 . 07 7 . 94 7 12 5 . 97 8 58 9 WH E E L I N G & U . O F F . E X P E N S E BP A I n t e r t i e Oth e r 73 . 62 6 , 33 1 6, 4 5 4 , 17 3 59 7 , 52 9 6, 4 5 0 . 61 0 16 8 . 58 7 43 2 , 82 3 62 4 , 83 9 81 2 , 48 4 61 4 23 7 61 3 , 22 7 24 6 , 32 2 80 3 , 87 7 80 7 . 64 3 -- - - - -- - - -- - - - - TO T A L W H E E L I N G & U . O F F . E X P E N S E 73 . 62 6 . 33 1 6, 4 5 4 , 17 3 59 7 52 9 45 0 , 61 0 16 8 , 58 7 43 2 , 82 3 62 4 , 83 9 81 2 , 46 4 61 4 23 7 61 3 , 22 7 24 6 32 2 80 3 . 87 7 80 7 64 3 TH E R M A L F U E L B U R N E X P E N S E Ce n l r a l i a Da v e J o h n l t o n 30 , 21 4 , 11 1 60 3 , 47 6 35 1 52 7 80 3 , 47 6 02 1 , 97 6 24 6 98 6 51 9 . 49 4 60 3 , 4 7 6 60 3 . 4 7 6 51 9 , 4 9 4 00 4 . 34 4 01 7 89 5 11 8 49 1 Jim B r i d g e r 92 . 20 8 , 06 6 44 6 56 3 63 1 , 54 8 29 7 70 0 09 4 , 30 7 50 8 , 21 5 74 7 , 4 4 2 51 8 , 42 0 8,4 5 0 , 31 5 16 5 , 06 0 44 6 36 1 46 1 , 15 7 44 0 . 97 8 Wy o d o k 19 , 48 9 , 70 5 86 2 , 99 9 68 2 71 3 50 2 , 41 6 80 0 , 4 0 2 86 2 , 99 9 80 2 90 7 86 2 , 99 9 86 2 99 9 29 0 . 36 5 33 5 . 16 7 29 0 , 36 5 1.3 3 3 37 4 Co l o l r i p 10 9 , 03 1 70 7 , 68 0 31 8 43 4 35 5 , 05 7 68 4 09 6 70 7 , 88 0 68 5 04 6 70 7 , 88 0 70 7 , 88 0 68 5 , 04 6 52 2 , 69 0 50 5 , 15 2 52 1 99 0 Ca r b o n 95 8 , 47 4 77 2 , 32 3 69 7 , 58 3 47 2 , 4 8 5 49 8 , 67 2 77 2 , 32 3 74 7 , 4 0 8 77 2 32 3 77 2 , 32 3 74 7 , 40 8 91 2 , 48 5 88 1 , 87 2 91 1 , 26 9 Na u g h t o n 57 , 55 1 , 55 4 15 5 59 4 65 8 , 67 0 66 1 , 17 3 05 8 , 14 5 63 3 , 38 3 98 9 , 28 7 94 5 , 02 5 15 5 59 4 98 9 , 28 7 16 2 . 53 5 98 9 , 28 7 15 5 , 59 4 Hu n t i n 9 t o n 43 . 67 4 00 5 01 6 , 83 9 62 8 , 11 1 01 6 . 83 9 97 4 , 00 1 30 3 . 65 7 88 7 , 26 6 01 6 , 83 9 01 6 83 9 68 7 . 26 8 02 2 , 24 3 68 7 , 26 6 01 6 . 83 9 Hu n t e r 67 , 89 6 , 91 5 84 1 , 45 6 57 7 , 62 3 51 1 08 2 26 5 , 58 0 6, 4 8 3 , 41 6 27 4 , 27 5 6, 4 8 3 , 4 1 6 6,4 8 3 , 41 6 27 4 , 27 5 55 0 70 2 60 8 , 44 3 54 3 , 25 1 Bl u n d e l l 81 5 , 73 7 33 6 , 04 5 30 3 . 52 4 19 5 , 12 3 32 4 , 75 6 33 6 , 04 5 32 5 , 20 5 33 6 04 5 33 6 , 04 5 32 5 20 5 33 8 . 49 4 32 5 20 5 33 8 , 04 5 Ch o l l a 29 , 85 9 , 73 4 32 2 , 89 4 55 1 , 30 7 83 0 85 4 92 9 , 27 7 83 4 . 78 4 92 9 , 27 7 92 9 27 7 83 4 , 78 4 93 3 . 21 9 83 4 78 4 92 9 , 27 7 Cr a i g 13 , 90 6 , 59 4 23 7 , 02 7 11 7 31 8 79 8 , 12 2 19 5 46 1 23 7 , 02 7 19 7 , 12 0 23 7 , 02 7 23 7 , 02 7 19 7 12 0 23 8 , 69 7 19 7 , 12 0 01 7 , 52 8 Ha y d e n 02 3 , 97 3 58 0 , 4 6 6 52 4 29 1 24 8 , 25 5 31 4 , 82 5 58 0 , 46 6 58 1 , 75 2 58 0 , 4 6 6 58 0 , 4 6 6 58 1 75 2 58 1 , 25 7 56 1 , 75 2 34 8 22 5 Ga d l b y 41 , 58 5 , 00 9 40 5 , 82 5 07 6 , 25 3 3,4 0 5 , 82 5 25 6 , 74 2 36 5 33 1 91 4 . 37 0 13 6 95 1 3,4 0 5 , 82 5 64 2 , 91 1 03 8 . 63 4 90 3 11 9 03 3 , 22 3 He r m i o t o n 26 , 31 7 , 49 6 33 2 , 64 7 10 6 90 5 33 2 , 64 7 25 4 , 26 5 74 9 47 8 69 3 , 04 6 33 2 64 7 33 2 , 64 7 25 7 . 39 5 33 5 . 77 7 25 7 , 39 5 33 2 , 64 7 Fix e d C o o l 15 , 86 2 . 39 6 32 1 . 66 6 32 1 . 66 6 32 1 , 86 6 32 1 . 86 6 1.3 2 1 , 66 6 32 1 . 8 6 6 32 1 , 86 6 32 1 , 86 6 1.3 2 1 , 86 6 32 1 . 86 6 32 1 , 86 6 32 1 , 86 6 -- - -- - - - -- - -- - - - -- -- - - TO T A L F U E L B U R N E X P E N S E 46 4 , 4 7 2 , 80 0 37 . 94 3 . 90 0 99 4 . 36 6 35 , 27 3 , 37 3 34 . 89 5 , 92 8 39 . 03 8 , 32 9 38 . 50 1 , 26 8 78 4 , 65 7 42 . 19 5 . 99 5 40 . 69 9 , 23 4 40 . 74 2 . 47 1 38 , 04 2 , 67 8 41 . 38 0 , 59 7 -- -- - - -- - -- - -- - - -- - -- - -- - -- - - NE T P O W E R C O S T 61 4 , 89 9 , 04 1 87 6 , 81 0 50 , 09 4 . 73 8 62 9 , 44 2 57 , 54 9 , 97 1 49 , 55 8 , 65 4 56 9 , 17 1 85 , 02 4 , 63 1 77 3 66 4 47 . 46 4 , 82 8 27 , 55 9 94 0 30 , 54 8 , 65 1 25 0 , 53 7 -- - - -- - - ~ - Ne l Po w e r Co s I I N e l S y o / e m Lo o d 11 . 10 . 11 . 12 . 14 . 11 . 12 . 17 . 15 . 11 . 2 2 _P I 8 n n l n g 02 J 2 0 I 2 0 0 2 I I , e o A M _I I P A D R I . I8 b . . . . Pa c i t i C o r p PD l M a c ; S l u d y R . . . 1 1 a 31 - Ma y - 1: 5 5 " . , UE 11 6 . Bri 6 f Ne t P o w e r C o s t E n e r g y A n a l y a i s Pe r i o d e n d i n g 12 1 2 0 0 1 (M W H ) 20 0 1 Ja n Fe b Ma r Ap r Ma y Ju n Ju t Au g Sa p Oc t No v De e NE T S Y S T E M L O A D 53 , 14 3 , 89 0 75 7 , 13 8 29 7 , 44 0 24 8 , 24 0 05 8 , 59 8 23 9 , 31 2 34 8 08 0 83 3 , 02 4 70 0 , 59 2 23 2 18 0 31 8 , 02 0 31 2 , 80 0 80 0 , 28 8 SP E C I A L S A L E S F O R R E S A L E Bla c k H i l l s 45 5 52 0 88 8 34 , 94 4 38 , 68 8 38 8 68 8 37 , 4 4 0 88 8 38 , 88 8 37 , 44 0 38 , 74 0 37 , 4 4 0 88 8 So C a l E d i s o n ( P ) 81 3 20 0 08 0 47 , 04 0 52 , 08 0 33 0 08 0 50 , 40 0 52 , 08 0 52 , 08 0 50 , 40 0 52 , 15 0 50 . 4 0 0 08 0 So C a l E d i s o n ( U ) 81 3 , 20 0 52 , 08 0 47 , 04 0 08 0 50 , 33 0 52 , 08 0 50 . 4 0 0 52 , 08 0 52 , 08 0 50 . 4 0 0 15 0 50 . 4 0 0 52 , 08 0 SM U D 35 0 , 15 3 19 , 07 7 90 9 55 3 38 3 21 , 99 0 90 5 28 , 35 9 25 , 95 3 88 2 38 . 4 8 1 43 , 59 5 08 8 IP P S a l a 54 1 95 3 48 , 0 0 3 47 , 14 2 45 4 84 3 78 2 48 , 18 1 07 9 07 5 48 , 58 2 47 , 17 5 53 , 71 7 94 0 Pu g e t P o w e r I I 05 4 , 08 0 89 , 28 0 52 0 89 , 28 0 88 , 28 0 89 , 28 0 88 , 4 0 0 89 , 28 0 28 0 88 , 4 0 0 89 , 4 0 0 88 , 4 0 0 89 , 28 0 Sia r r a P a c i f I C I I 45 9 , 90 1 39 , 08 0 28 0 39 , 08 0 37 , 74 8 39 , 08 0 80 0 39 , 08 0 08 0 80 0 11 3 80 0 39 , 08 0 UM P A S a l a 35 , 04 0 97 8 88 8 97 6 87 8 97 8 88 0 97 6 97 8 88 0 98 0 88 0 97 8 CD W R S a l e 61 3 , 20 0 52 , 08 0 04 0 52 , 08 0 50 , 33 0 52 , 08 0 50 , 4 0 0 52 , 08 0 52 , 08 0 50 . 4 0 0 15 0 50 . 4 0 0 52 , 08 0 WA P A S a l e 48 4 , 28 0 39 , 43 2 81 8 39 , 4 3 2 38 , 10 7 39 . 4 3 2 38 , 16 0 39 . 4 3 2 39 , 43 2 38 , 18 0 39 . 4 8 5 18 0 39 , 43 2 WA P A I I S a l a PS C o S a l e 15 8 , 32 0 20 8 88 , 70 4 98 , 20 8 94 , 90 8 98 , 20 8 04 0 98 , 20 8 98 , 20 8 04 0 98 , 34 0 95 , 04 0 98 , 20 8 Cla r k S a l e 80 8 , 19 3 18 9 28 0 15 2 , 88 0 13 2 , 99 0 13 1 32 5 12 2 , 83 4 50 , 54 4 38 0 Ble c k H i l l a C a p a c i l y Sp r i n g f o a l d 25 9 , 94 8 17 , 85 8 18 , 81 8 28 , 78 4 28 , 78 0 29 , 78 0 80 0 78 4 83 2 14 . 4 0 0 14 , 90 0 14 , 40 0 17 , 85 8 PN G C 17 2 , 74 0 44 , 84 0 40 , 32 0 84 0 14 0 Ok a n 0 9 a n 53 5 08 0 38 8 79 5 02 0 93 5 72 8 12 5 97 8 52 8 UM P A I I S a l a 18 9 , 72 8 45 1 52 3 23 , 81 8 41 , 08 9 45 , 23 5 41 , 47 2 38 4 97 8 Sp r i n 9 f i e l d I I 14 5 , 78 7 21 , 31 8 19 , 25 3 31 8 10 , 30 0 10 , 31 4 21 , 34 4 20 , 82 8 21 , 31 8 Co w l i t z - BH P 08 0 95 2 37 8 95 2 75 2 95 2 78 0 95 2 95 2 78 0 98 0 78 0 95 2 Cla r k - 83 , 22 1 08 8 38 4 08 8 83 1 08 8 84 0 08 8 06 8 84 0 07 8 84 0 08 8 Hu r r i e s n a S a l a s 7. 4 2 4 83 2 55 2 83 2 81 1 83 2 81 2 83 2 83 2 81 2 83 3 81 2 83 2 AP P A - AE P C O 38 , 97 8 18 , 22 8 18 , 22 8 52 0 Cit i z e n s P o w e r 13 3 58 8 11 . 4 2 4 11 . 4 2 4 51 2 10 , 24 0 11 , 28 4 11 , 28 4 10 , 24 0 11 , 77 8 10 , 24 0 98 8 10 , 33 8 10 , 88 0 Gr e e n M o u n l a i n s 44 , 75 0 22 , 20 4 22 , 54 8 Fla t h e a d S a l a 81 3 , 20 0 52 , 08 0 47 , 04 0 52 , 08 0 33 0 52 , 08 0 50 . 4 0 0 52 , 08 0 52 , 08 0 50 . 4 0 0 52 , 15 0 50 . 4 0 0 52 , 08 0 BP A W i n d S a l a 53 , 84 5 73 2 87 8 49 3 84 5 10 5 24 1 44 8 98 9 89 0 42 5 58 2 5,4 5 9 SD G & E S a l a 87 6 , 00 0 74 . 4 0 0 87 , 20 0 74 , 40 0 71 , 90 0 74 , 40 0 72 , 00 0 74 . 4 0 0 74 . 4 0 0 72 , 00 0 74 , 50 0 72 , 00 0 74 . 4 0 0 Sh o r t T e r m F ; - m P 84 4 70 0 81 1 31 8 58 9 , 10 5 82 4 02 0 53 4 , 93 8 28 0 59 1 43 2 , 75 7 18 1 , 09 8 25 4 , 98 0 29 2 , 71 3 54 8 , 24 3 48 9 25 2 80 5 89 1 Sh o r t T e r m F ; - m I n l e r l i a 57 8 , 74 7 94 . 4 1 4 91 , 4 3 8 15 5 , 97 7 11 7 18 0 10 4 16 0 07 8 10 , 50 0 Sh o r t T e r m F i r m U 11 7 , 28 2 57 4 58 7 54 3 02 0 58 8 , 24 4 58 0 . 4 2 8 49 2 74 7 48 4 , 88 3 24 1 95 2 24 2 , 30 9 48 2 , 85 3 81 3 , 74 7 85 7 . 4 2 2 87 7 , 29 2 Se c o n d a r y S a l e s 17 3 , 58 0 18 3 , 48 9 24 8 , 32 2 20 9 78 2 47 , 38 6 37 , 41 8 57 1 18 8 , 74 4 18 3 , 88 1 13 4 , 92 5 28 7 , 4 0 5 27 3 , 70 2 40 9 , 19 5 Na v a d a 45 , 90 1 98 9 10 , 85 7 15 8 28 0 47 0 33 3 84 8 18 8 Fo u r C o r n e r s 37 1 . 4 8 4 18 1 1.4 8 8 ' 38 , 38 7 32 , 05 4 13 9 16 6 , 04 2 12 2 . 4 0 2 79 3 No r t h w e . t 74 5 , 88 8 20 1 88 8 32 , 74 2 08 0 83 1 11 , 82 5 36 , 51 6 12 5 95 8 84 8 13 3 , 14 7 20 5 , 05 2 SW l n t e r t i a 92 7 , 85 9 78 , 98 1 18 1 , 59 4 15 4 73 4 53 3 21 4 , 55 5 13 0 54 2 18 2 , 94 0 Se c o n d a r y L o s . . . 82 , 47 0 33 8 00 2 88 4 91 9 25 3 43 2 80 7 74 3 10 3 14 , 38 1 10 , 01 3 03 5 -- - - - - - -- - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - -- - - - - - - - - - -- - - - - - - -- - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - _u _ - - - TO T A L S P E C I A L S A L E S 24 , 37 8 12 9 31 7 , 98 0 25 5 , 20 7 29 9 59 9 05 1 , 75 8 74 8 , 37 9 78 8 , 4 4 0 59 1 , 4 7 5 58 1 , 19 0 1.7 7 8 , 81 1 19 8 95 9 18 3 , 84 8 84 4 70 7 -- - - - -- - - - - - - - -- - - - - - - - - - - - - -- - - - - - - - - - -- - - - - - - - - - - - - - - - -- - - - - - - - -- - - - - - -- - - - - -- - - - - - - - - -- - - - -- - - - - - -- - - - -- - - - - - -- - -- - - - - - - - - -- - - - - - - - -- -- - - - - - - - -- - TO T A L R E Q U I R E M E N T S 77 , 51 9 81 9 07 5 , 09 8 55 2 , 84 7 54 7 83 9 10 8 , 35 4 98 7 , 89 1 11 4 , 52 0 8. 4 2 4 . 4 9 9 28 1 , 78 2 01 0 97 1 51 4 , 97 9 8, 4 7 8 , 4 4 8 7.4 4 4 , 99 5 -- - - - - -- == = = -- - - =- - - -- - == = ~ ~ = = == = = = = = = ~ - -- - - == = =~ ~ - - - - - PU R C H A S E D P O W E R & N E T I N T E R C H A N G E BP A S u p p l e m e n t a l C a p . c i l y Bl a c k H i l l s C a p a c i l y 05 8 15 2 73 7 13 3 38 3 87 8 47 8 81 5 24 4 30 2 Co G a n / J a m a s Riv e r 37 3 , 52 8 72 4 28 , 65 4 72 4 30 , 85 8 31 , 72 4 70 1 31 , 72 4 72 4 30 , 70 1 78 7 30 , 70 1 31 , 72 4 Mid C o l u m b i a 91 0 , 83 8 21 2 52 7 19 1 , 04 0 15 9 97 8 11 8 , 39 8 15 8 53 4 18 7 , 57 7 18 8 06 2 14 7 , 68 2 13 4 , 02 7 15 9 29 2 12 8 , 99 1 18 6 72 8 Ca n a d i a n E n t i l l a m a n l (7 4 , 89 7 ) (8 , 38 1 ) (5 , 74 8 ) (8 , 38 1 ) (8 , 14 7 ) 38 1 ) (8 , 15 8 ) 38 1 ) (6 , 36 1 ) (8 , 15 8 ) 37 0 ) (8 , 15 8 ) (8 , 36 1 ) CS P E 82 , 98 3 07 2 29 1 88 1 14 0 35 3 14 8 35 3 35 3 23 0 7.4 8 1 23 0 7. 4 7 1 Co l o c k u m (1 7 4 , 4 4 2 ) (1 8 , 05 9 ) (1 4 , 87 9 ) (1 9 , 94 9 ) (1 3 28 8 ) (2 , 92 3 ) 17 3 ) (1 0 , 40 8 ) (1 4 80 8 ) (2 0 12 0 ) (2 3 , 21 8 ) (1 8 , 55 9 ) (1 9 , 28 0 ) Gr a n L C o u n l y 87 , 42 8 39 4 81 8 81 8 40 9 34 2 99 8 27 8 55 9 09 6 90 0 72 8 09 0 PG E Co v a 23 , 18 2 02 8 88 4 02 8 97 8 02 8 98 0 02 8 02 8 98 0 03 0 98 0 21 0 IP C Re t u r n (9 3 , 50 0 ) (7 , 30 9 ) 35 9 ) (8 , 34 2 ) (8 , 88 0 ) (9 , 05 1 ) 77 8 ) (9 , 88 9 ) 10 9 ) (8 , 4 8 9 ) (8 , 87 0 ) 11 8 ) 55 0 ) F. C o n t r a c t s - P P & L 51 8 , 20 8 44 , 87 5 42 , 70 3 50 , 41 8 54 , 01 0 51 , 03 1 17 3 41 , 18 8 39 , 32 5 92 4 31 , 77 7 38 , 39 2 42 , 39 4 Tr i S t a t e P u r c h a . e 28 3 94 8 24 , 18 0 08 7 24 , 18 0 38 8 24 , 18 0 23 . 4 0 0 24 , 18 0 18 0 23 , 40 0 21 3 23 , 40 0 24 , 18 0 So u t h I d a h o Uta h t o G o s h e n A r e a (2 5 1 20 0 ) (2 8 , 05 8 ) (1 7 , 01 2 ) 13 9 02 8 42 4 (5 4 7 ) (8 , 97 8 ) 22 9 ) (8 , 85 3 ) (4 7 90 8 ) (8 8 38 3 ) (8 5 , 84 5 ) So u t h I d a h o BP A 1 0 P a c i f I C 42 3 , 83 4 83 8 47 , 87 1 25 , 87 0 17 , 21 5 15 , 88 8 98 9 97 8 22 9 88 2 47 , 93 2 88 , 34 8 85 , 88 2 So u t h I d a h o St o r a g e 87 , 92 2 93 6 81 9 57 6 17 , 38 5 98 1 14 , 75 3 14 , 88 4 1.4 9 7 (1 ) 29 2 So u t h I d a h o Re t u r n o f S t o r a g e (8 8 , 18 9 ) 59 8 ) (9 . 4 9 9 ) (8 . 4 1 9 ) 25 9 ) (1 , 10 3 ) (1 ) (5 1 ) 98 9 ) (2 7 , 34 1 ) AP S P u r c h a . e 84 5 10 0 57 8 77 8 20 0 82 2 Tr i S t a t e E x c h a n g e 37 2 11 0 18 , 54 5 73 9 (1 8 , 28 5 ) (1 8 , 78 9 ) (1 4 , 74 8 ) (1 4 06 5 ) (2 8 , 99 2 ) (2 3 14 8 ) 22 , 88 5 20 , 58 0 20 , 53 8 SC E P u r c h a . e 18 , 31 3 28 5 58 0 1.4 8 7 BP A E x c h a n g e (1 ) (5 0 , 00 0 ) 13 3 , 33 3 11 8 , 88 7 (8 8 , 88 7 ) (8 8 88 7 ) (8 8 , 88 7 ) Av i o t a S u m m e r P u r c h a s e 82 , 80 0 13 , 50 0 27 , 90 0 27 , 90 0 13 , 50 0 Av i . t a E x c h a n g e 30 0 (9 , 30 0 ) (8 , 4 0 0 ) 50 0 00 0 30 0 50 0 (9 , 30 0 ) Ge m S t a t e 89 5 50 9 18 , 15 0 93 8 18 , 29 5 14 , 00 3 GS L M 30 , 4 7 8 4. 4 8 4 03 2 4. 4 8 4 31 4 4.4 8 4 32 0 49 0 1. 4 4 0 1.4 8 8 QF C o n t r a c t s - U P & L 48 4 99 0 41 , 99 1 38 , 20 7 42 , 12 7 37 , 11 6 39 , 23 9 42 , 92 8 71 6 43 , 51 5 37 4 38 , 85 8 65 2 41 , 47 1 IP P P u r c h a s e 54 1 , 95 3 48 , 00 3 14 2 45 4 44 , 84 3 78 2 18 1 42 , 07 9 51 , 07 5 48 , 58 2 47 , 17 5 53 , 71 7 48 , 94 0 He r m i s t o n P u r c h a . e 89 1 , 95 2 18 7 , 13 2 15 0 , 95 8 18 7 13 2 18 1 , 51 8 12 8 , 58 3 12 4 41 8 18 7 , 13 2 18 7 , 13 2 18 1 , 74 1 18 7 , 35 7 16 1 74 1 16 7 , 13 2 -- n o 02 l 2 O l 2 O O 2 ",O O A M _I I P l l C A ' . ". " " De s e r e t A n n u a l De s e r e l M o n l h l y De s e r e l E x p a n s i o n 22 1 , 09 2 19 , 31 3 95 7 14 , 13 1 16 , 64 0 14 5 ' 17 , 74 4 21 1 18 , 33 1 19 , 74 1 18 , 22 9 18 , 63 7 20 , 01 3 De s e r e t N F P u r c h a s e 89 , 05 6 33 , 08 8 14 4 25 , 82 4 AP S E x c h a n g e 73 7 ) 14 2 64 8 62 , 28 7 (7 1 , 42 4 ) (1 3 8 24 0 ) (1 4 2 , 6 4 8 ) (1 4 2 64 8 ) (6 9 , 12 0 ) 52 0 13 8 , 24 0 14 2 , 64 8 Hu r r i c s n e P u r c h a s e 96 1 Fo o t e C r e e k 12 1 22 7 12 , 90 6 10 , 53 2 12 , 36 8 10 , 90 8 99 0 29 8 75 9 68 3 75 7 12 , 21 4 12 , 52 1 12 , 29 1 Re d d i n 9 E x c h a n g e (3 ) 83 3 83 3 10 . 83 3 10 , 83 3 (5 , 00 0 ) 00 0 ) (1 6 , 66 7 ) (1 6 , 68 7 ) (1 6 66 7 ) (5 , 0 0 0 ) 10 , 83 3 10 , 83 3 Tr a n s A l t a P u r c h a s e 23 1 , 61 6 14 6 , 56 8 13 2 , 36 4 14 6 , 56 8 14 1 , 64 0 14 6 , 56 8 21 2 , 76 0 21 9 , 85 2 21 9 , 85 2 21 2 76 0 21 9 85 2 21 2 , 76 0 21 9 , 85 2 En r o n P u r c h a s e 12 3 , 20 0 10 , 4 0 0 60 0 10 , 80 0 10 , 40 0 10 , 40 0 10 , 4 0 0 10 , 40 0 10 , 80 0 60 0 10 , 80 0 60 0 10 , 00 0 DS M P r o g r a m 11 8 , 26 0 85 5 85 5 85 5 85 5 85 5 85 5 85 5 85 5 85 5 85 5 85 5 85 5 T& D E f f I c i e n c i e s P P L 26 , 28 0 23 2 01 6 23 2 15 7 23 2 16 0 23 2 23 2 16 0 23 5 16 0 23 2 T& O E f f i c i e n c i e s U P L 76 0 74 4 67 2 74 4 71 9 74 4 72 0 74 4 74 4 72 0 74 5 72 0 74 4 ST F P u r c h a s e s P P L 60 8 , 07 5 67 5 65 3 70 9 , 74 3 79 5 , 13 6 55 8 , 07 4 42 2 , 27 9 32 2 , 78 8 29 8 , 57 9 42 1 71 5 47 6 , 38 0 51 8 , 53 0 59 8 32 4 81 0 , 87 4 ST F P u r c h a s e s U P L 38 8 , 65 7 77 6 , 75 5 82 9 , 4 4 2 74 2 . 91 5 93 1 83 1 50 3 , 86 7 58 1 , 50 3 56 5 , 4 8 5 43 5 23 5 37 5 , 60 0 54 3 , 56 4 44 1 48 3 66 0 , 95 7 Ss c o n d a r y P u r c h a s e s 06 3 , 03 0 10 6 , 50 9 89 , 38 0 11 2 , 34 9 37 , 74 3 90 , 53 7 06 3 98 , 70 7 11 0 , 60 7 59 , 60 5 06 9 10 8 , 00 0 10 5 46 1 -- - - - - - - - - n _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - -- - - - - - - - -- - - - - - _ _ _ _ _ n - _ _ _ _ _ _ n _ _ _ - - - - - - - - -- - - - - - - - -- - - - - - TO T A L P U R C H A S E D P W & N E T I N T . 24 , 23 7 , 66 6 58 3 , 38 3 2, 4 5 7 , 06 1 36 3 86 8 20 7 , 14 8 63 7 , 4 5 7 73 3 , 29 5 75 0 , 33 5 60 8 , 60 9 46 4 , 55 7 93 6 , 39 4 97 9 , 90 5 49 5 , 65 4 CO A L F I R E D G E N E R A T I O N Cs n l r a l i a Da v e J o h n s t o n 67 0 , 79 1 51 1 , 40 8 46 1 , 91 7 51 1 , 40 8 39 7 , 38 1 44 2 17 1 49 4 , 91 1 51 1 , 4 0 8 51 1 , 4 0 8 49 4 , 91 1 32 7 54 9 49 4 . 91 1 51 1 , 4 0 8 Jim B r i d g e r 10 , 4 5 4 , 25 1 95 9 , 4 2 1 86 6 57 2 71 5 , 87 2 69 0 , 4 8 3 95 9 , 4 2 1 76 0 11 9 95 9 , 42 1 95 9 , 4 2 1 92 8 , 4 7 1 96 0 , 71 0 73 4 , 91 9 95 9 , 4 2 1 Wy o d a k 23 8 , 88 8 19 3 , 33 0 17 4 62 1 15 5 , 91 1 18 6 , 83 4 19 3 , 33 0 18 7 , 09 4 19 3 , 33 0 19 3 , 33 0 18 7 , 09 4 19 3 , 59 0 18 7 , 09 4 19 3 , 33 0 Co l s l r i p 08 0 , 67 0 99 , 85 5 44 , 91 9 08 5 50 0 99 , 85 5 96 , 63 4 85 5 99 , 65 5 98 , 63 4 99 , 96 9 98 , 63 4 99 , 85 5 Ce r b o n 31 8 , 12 3 11 9 , 12 3 10 7 , 59 5 72 , 87 6 91 5 11 9 12 3 11 5 , 28 0 11 9 , 12 3 11 9 , 12 3 11 5 28 0 11 9 , 28 2 11 5 28 0 11 9 , 12 3 Na u g h t o n 5, 4 0 7 , 78 2 46 4 , 44 1 43 7 , 56 0 34 4 , 01 9 38 1 , 32 0 43 5 , 37 0 46 8 , 81 4 46 4 , 65 5 46 4 , 44 1 46 8 81 4 48 5 , 09 3 46 8 , 81 4 48 4 , 44 1 Hu n t i n g t o n 50 6 , 91 5 59 8 . 46 2 54 0 , 54 6 59 8 46 2 29 4 , 10 3 34 3 , 21 8 57 9 , 15 7 59 8 , 46 2 59 8 , 46 2 57 9 , 15 7 59 9 , 26 7 57 9 , 15 7 59 8 , 46 2 Hu n t e r 24 1 , 88 0 44 8 70 7 53 4 , 69 6 64 3 , 73 0 73 1 85 8 75 7 , 30 5 73 2 87 6 75 7 , 30 5 75 7 , 30 5 73 2 , 87 6 75 8 32 3 62 9 , 59 4 75 7 , 30 5 Bl u n d e l l 17 0 , 01 6 14 , 97 3 52 4 69 4 14 , 4 7 0 14 , 97 3 14 , 4 9 0 14 , 97 3 14 , 97 3 14 , 4 9 0 14 , 99 3 14 , 49 0 97 3 Ch o l l a 2,4 7 6 81 9 10 9 , 73 2 21 1 , 62 7 23 4 , 81 5 24 2 , 97 9 23 5 14 1 24 2 , 97 9 24 2 , 97 9 23 5 , 14 1 24 3 , 30 6 23 5 14 1 24 2 , 97 9 Cr a i g 34 0 , 61 4 11 9 25 1 10 7 71 1 76 , 94 0 11 5 , 24 4 11 9 , 25 1 11 5 40 4 11 9 , 25 1 11 9 , 25 1 11 5 , 4 0 4 11 9 , 4 1 2 11 5 , 40 4 98 , 09 1 Ha y d e n 54 8 , 83 1 52 , 88 5 76 7 22 , 61 8 28 , 68 3 52 , 88 5 51 . 18 0 52 , 88 5 52 , 88 5 51 , 18 0 52 , 95 7 51 , 18 0 31 , 72 6 Ga d s b y 98 3 , 81 8 80 , 57 5 72 , 77 8 57 5 77 , 04 8 61 7 68 , 94 8 21 4 80 , 57 5 16 4 95 , 54 6 92 , 34 0 95 , 4 1 8 Hs , m i s l o n 93 3 , 98 0 17 1 , 41 8 15 4 82 9 17 1 , 4 1 8 16 5 , 65 8 12 8 , 58 3 12 4 , 41 8 17 1 41 8 17 1 , 41 8 16 5 , 88 8 17 1 , 64 8 16 5 , 86 8 17 1 41 8 -- - - - - - - - - - - - - -- - - - - - - - - - - -- - - - - -- - - - - - - -- - - -- - - - - - - - - - -- - - - - - -- - - - - - - - - - - - - - - - - - - -- - - - - - - - -- - - - -- - - TO T A L C O A L F I R E D G E N E R A T I O N 48 , 37 3 , 37 8 96 3 , 58 1 56 5 03 5 66 4 , 23 5 49 1 , 31 2 98 8 , 06 1 04 4 46 4 37 9 , 27 9 4,4 0 5 , 4 2 6 27 1 , 52 4 24 1 , 68 5 98 0 , 64 6 37 7 , 9 5 0 SY S T E M H Y D R O Sy s t e m H y d r o 90 8 71 6 53 0 , 64 6 53 3 , 71 7 51 4 44 0 40 9 25 1 36 2 , 17 3 33 6 , 76 1 29 4 , 88 5 24 7 74 7 25 4 , 89 0 33 6 , 92 0 51 5 , 69 5 57 1 , 39 1 Dr a f t F r o m S t o r a g e (2 , 71 4 ) (3 , 16 8 ) 29 6 64 3 -- - - - - -- - -- - - - - -- - - -- - - - - - - - -- - - - - - -- - - TO T A L S Y S T E M H Y D R O 90 8 77 5 52 8 , 13 2 53 0 , 55 1 51 9 , 73 6 40 9 , 89 4 36 2 , 17 3 33 6 , 76 1 29 4 , 68 5 24 7 , 74 7 25 4 , 69 0 33 6 , 92 0 51 5 69 5 57 1 , 39 1 =-- - - ~ -- - - == - - - -- - - - - - - - =~ ~ -- - - - == = = = - ~ =- - - ~ = -- - - - -~ = TO T A L R E S O U R C E S 77 , 51 9 , 81 9 07 5 09 6 55 2 64 7 54 7 , 83 9 10 8 , 35 4 98 7 , 69 1 11 4 52 0 6,4 2 4 , 49 9 26 1 , 78 2 01 0 , 97 1 51 4 , 97 9 6, 4 7 6 , 44 6 44 4 , 99 5 -- - - - -- - - - - - -- - - -- - - - - -- - - -- - -- - - - - - -- - _" . " D R I . le b . ,," -" ' . " " ' 1 1 O2 J 2 O I 2 D O 2 IU O A M PacifiCorplP AC- February 5 2002 lIP A Data Request No. 1. lIP A Data Request No. 1.16: With respect to the footnotes found in Widmer s Exhibit 7 please answer the following: Please provide a detailed explanation and quantification of the data that went into formulating the figures associated with footnote 2. Emphasis should be placed upon the treatment from each jurisdiction of jurisdictional customers, system finn customers, and system non-finn customers. Please reconcile the 1998 Net System Load listed in footnote 2 with the system loads listed on page 304 of the 1998 FERC Fonn I. Please provide this on a sales as well as a generation level basis. Please provide a detailed explanation and quantification of the data that went into formulating the figures associated with footnote 4. Emphasis should be placed upon the treatment from Idaho of jurisdictional customers, system finn customers, and system non- finn customers. Please reconcile the 1998 Idaho Retail Load listed in footnote 4 with the Idaho loads listed on page 304 of the 1998 FERC Fonn 1. Please provide this on a sales as well as a generation basis. Please provide a detailed explanation and quantification of the data that went into formulating the figures associated with footnote 6. Emphasis should be placed upon the treatment from each jurisdiction of jurisdictional customers, system firm customers, and system non- finn customers. What is the timeframe associated with the values included in footnote 6? For each month during the November 1 2000 through October 31 2001 timeframe, what was the actual Idaho Retail Load on the same basis as footnote 4? For each month during the November 1 2000 through October 31 2001 timeframe, what was the actual Idaho Retail Load (stating special contracts separately) as would appear on the FERC Fonn I? Please provide this infonnation on a sales as well as generation level basis. PacifiCorplP AC- February 5, 2002 lIPA Data Request No. 1.16 Response to lIP A Data Request No. 1.16: The Company s total net system load is all retail load in the Company s service territories, including both firm and non-firmload. The In-Rate net system load is the temperature normalized actual net system load for the corresponding month in 1998. FERC Form 1 reports the retail load at the sales level by customer class. The total net system load used in the net power cost studiesis the retail load at the generation level with temperature normalization. Retail load at generation by customer class is notavailable. The figures associated with footnote 4 are the Idaho retail loads for each month during 1998. These include just Idaho jurisdictional non-interruptible customers. The loads are adjusted to normalize temperature. See Attachment lIP A 1.16d. This is the same total net system load as described in a. above except that they are actual load without adjustments. November 2000 through October 2001. See Attachment lIP A 1.16g. See Attachment lIP A 1.16h. Witness: Mark T. Widmer IDAHO CASE NO. PAC-O2- ACIFICORP lIP A DATA REQUEST ATTACHMENT lIP A 1.16(d) ATTACHMENT IIPA 1.16d RECONCILIATION OF MWH SOLD AND LOAD 1998 Form 1 Page 304. Idaho Sales Residential 1 Residential 7 Security Area Lighting 36 Residential Service Unbilled Revenue Commercial 6 - General Service 6A General Service - Large Power 7 Security Area Lighting 9 General Service 19 Commercial & Industrial 23 General Service 23A General Service 35 General Service Optional Unbilled Revenue Industrial 6 General Service Large Power 6A General Service - Large Power 7 Security Area Lighting 8 General Service 9 General Service 10 Irrigation and Soil 12 Street Lighting 19 Commercial & Industrial 23 General Service 23A General Service 35 General Service Distribution BPA Balancing Account Special Contracts Unbilled Revenue Street Lighting 11 Company Owned 12 Customer Owned Unbilled Revenue Total Per Form 1 Page 304 Less: Interruptible Included Above Idaho Sales less interruptible Idaho Load (excluded interruptible in 1998) Line Losses DJWb. 257,067 314 305,845 (16,555) 140,751 15,448 305 22,230 15,160 66,641 11,649 121 (5,583) 72,009 10,035 040 100,184 493,143 421 591 800 501 (67 488) 543,477 884 131 769 (81) 988,853 (1,328,843) 660,010 974 986 314,976 IDAHO CASE NO. P AC-O2- ACIFICORP lIP A DATA REQUEST ATTACHMENT lIP A 1.16(g) ATTACHMENT IIPA 1.16g IDAHO RETAIL mwh ImaI Interruptible thn Oct-oo 260,506 115,990 144,516 Nov-OO 218,875 86,619 132,256 Dec-OO 253,380 114 415 138,965 Jan-Q1 244,057 102,396 141,661 Feb-O1 352,870 85,455 267 415 Mar-Q1 361,806 115,291 246,515 Apr-Q1 364 520 112,299 252,221 May-Q1 298,985 115,091 183,894 Jun-Q1 275,704 110,291 165,413 Jul-Q1 246,971 96,414 150,557 Aug-Q1 219 197 81,869 137 328 Sep-O1 265,539 110,539 155 000 362,410 246,669 115,741 Note: October 2001 not available at this time ID AH CASE NO. PAC-O2- P A CIFI CO lIP A DATA REQUEST ATTACHMENT IIPA 1.16(h) ATTACHMENT IIPA 1.16h THLY IDAHO RETAI mwh ImaI Special Contracts Od-OO 205,831 130,874 957 Nov-OO 173,815 125,400 48,415 Dec-OO 246,431 97,140 149,291 Jan-o1 254,676 129,088 125,588 Feb-O1 210,947 120,397 90,550 Mar-o1 213,010 101,618 111,392 Apr-o1 219,078 133,526 85,552 May-o1 279,514 129,369 150,145 Jun-o1 301,820 132,808 169,012 Jul-o1 370,896 125,800 245,096 Aug-o1 327,664 106,466 221,198 Sep-O1 236,976 99,434 137 542 040,658 431 920 608,738 DATED this 1st day of March, 2002. PacifiCorp s Res~onses to TIP A' First Production Request STOEL RIVES LLP John M. Eriksson Of Attorneys for PacifiCorp, dba Utah Power & Light Company CERTIFICATE OF SERVICE I hereby certify that on this 1st day of March, 2002 , I caused to be served, via overnight delivery, a true and correct copy of the foregoing PacifiCorp' s Responses to the First Production Request of the Idaho Irrigation Pumpers Association to the following: Randall C. Budge Racine, Olson, Nye, Budge & Bailey O. Box 1391 201 E. Center Pocatello , ID 83204-1391 and that a true and correct copy of the foregoing was served on the following via overnight delivery: Scott Woodbury Deputy Attorney General Idaho Public Utilities Commission O. Box 83720 Boise, ID 83720-0074 Eric Olsen Racine, Olson, Nye, Budge & Bailey O. Box 1391 201 E. Center Pocatello, ID 83204-1391 Anthony Yankel 29814 Lake Road Bay Village, OH 44140 James R. Smith Senior Accounting Specialist Monsanto Company O. Box 816 Soda Springs, ID 83276 Tim Shurtz Firth City Councilman 411 South Main O. Box 46 Firth, Idaho 83236 PacifiCorp s Res~(onses to TIPA' First Production Request