EXHIBIT D...2005/01/19 · Exhibit D - Annual Load and Resource Forecast AVISTA CORP. Requirements and Resources figures in MW 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 line

EXHIBIT D

Location of Coyote Springs Plant Relative toA vista Utilities Service Area

Application of A vista CorporationCase No. AVU- O5-

SEE CASE FILE

FOR MAP(S)

EXHIBIT E

Excerpts from 2000 UpdatedIntegrated Resource Plan


July 12, 2000

A VISTA CORPORATION

1997 Integrated Resource Plan Update

I. Introduction:

Avista s last Integrated Resource Plan (IRP) was filed with the Commission on August 25, 1997.

That plan showed that the company was surplus for many years into the future. Since then many

things have changed in the electric utility industry and for A vista. Therefore, the company has

prepared this updated IRP to include those significant changes. As discussed later, this updatedIRP will also serve as the basis for a Request- for-Proposal (RFP) that A vista plans to issue.

The following information has been presented at various T AC meetings and will become aintegral part of the next IRP.

II. 1997 IRP Update

1. Load Forecast

The 2000 electric sales forecast was prepared during the summer of 1999. The forecast of firm

sales to the core-market is one of the most critical elements and was presented and discussed at

the T AC meeting. A vista Utilities utilizes econometric models to produce sales and customerforecasts. Econometric models are systems of algebraic equations which relate past economic

growth and development in the geographic communities served electricity with past customergrowth and consumption. The electrical energy forecast shows an annual average load of 1013 aMW in 2001 increasing to1159 aMW in 2009. The peak forecast shows 1594 MW in 2001 with 1851 MW in the year2009. The ten-year compound growth rate for residential usage is 2.3 percent, commercial is 3.percent and industrial is 1.6 percent. The overall total energy forecast has a compound growth

rate of 1.9 percent.

The annual load forecast numbers, for both peak and energy, through the year 2009 can be foundon the Requirements and Resources tabulation sheet.

2. Resource Assessment

CentraliaThe sale of the Centralia coal-fired plant resulted in the loss of 201 MW of capacity and 177

of annual energy from A vista s resource portfolio. The company entered into a short-term

contract with TransAlta, the new owners of Centralia, to replace a majority of the generation lostwith the sale of the plant. The term of this contract starts in July 2000 and extends through

December 2003.

A vista Corp - 1997 IRP UDdateExhibit EPage 1 of 5

costs and discharge less pollutants into the air than other fossil fuel plants. As shown in

Appendix B, the Northwest Power Planning Council costs for natural gas fired generationprojects range from approximately 41 mills to 43 mills.

At this point in time the following resources would not pass the initial screening. The following

costs are nominal life-cycle , levelized costs.

Nuclear: Costs are over the 100 mills per kilowatt-hour range. The total cost and the

lack of public acceptance make this resource option unacceptable.Coal: Costs are 80 to 90 mills. The total cost and cost uncertainty in air quality issuesmake this resource option unacceptable.Wind: Costs are 60 to 80 mills. There are indications that costs are declining but ourstudies show there are not favorable sites in our service territory so transmission costswould have to be added. Because wind is intermittent the resource would have to bediscounted for lack of capacity component. This would make this resource option

unacceptable.Geothermal: Costs are 80 to 100 mills making this resource option unacceptable.Solar: Costs are over 240 mills making this resource option unacceptable.

These costs are presented for general comparison purposes. The company will solicit resourcebids from the market in an upcoming Request-for-Proposals (RFP). The company is hoping for

innovative bids from project developers. The RFP bids will be evaluated against the informationthat has been gathered both internally and externally.

8. Load and Resource Summary

GeneralIncluded is Avista s annual Requirements and Resources (Load and Resource Summary) thatshows the company s load and resource position on an annual basis for the next ten years (seeAppendix D). It is dated June 1, 2000 and will be the same one used in the 2000 JRP. The peakcolumn is the January peak (the highest forecasted peak for the year) and the average column isthe annual 12-month average for the year. The resource peak numbers are what could be

expected as maximum capacity outputs during January. The hydro peak and energy numbers are

from the final regulation done by the Northwest Power Pool and reflect the reservoir levels inJanuary per the hydro regulation study (one-year critical period, 1936-37 water). The average

energy numbers are the expected 12-month averages for the loads, resources and contracts.

All the requirements are shown at the top of the page. Most of the purchases and sales contracts

end by the year 2004. The peak and average forecasted loads are shown on line 1 labeled

System Load. Line 17 Reserves are A vista s planning reserves and are part of the total

Requirements (as described in Section 3).

The Resource section is comprised of the resources and purchase contracts. Line 19 shows the

system hydro and line 20 is the contract hydro from the mid-Columbia PUD projects (with

critical water conditions). The mid-Columbia numbers decrease due to the Priest Rapids contract

ending in 2005 and the Wanapum contract ending in 2009. A vista is hopeful that a contract

extension can be negotiated with Grant County PUD. Lines 24 and 25 are the companys existing

A vista Corp - 1997 IRP UpdateExhibit EPage 2 of5

simple-cycle combustion turbines, and lines 33 and 34 are the expected thermal generationoutput from Kettle Falls and Colstrip.

Line 29 shows the BP A residential exchange contract and the 47 MW flat delivery of power tothe company from BP A. There is no dispatchability or flexibility with this contract. Althoughthis contract has not been signed, A vista feels it is firm enough to be included.

Line 44 is the Surplus (Deficit) numbers calculated by subtracting the Total Requirementsfrom

the Total Resource numbers. In the year 2004 A vista is 287 MW deficit on peak and 318 aMW

deficit on energy under critical water planning criteria.

Resource FlexibilityFlexible generation resources are a key component to meet the requirements of Avistacustomers. As depicted in the charts on pages 8 and 9 in Appendix E, A vista experiences load

changes of 100 MW or more during several hours of each day. Loads must be ramped up anddown under a variety of seasonal and load conditions. In order to meet the load, flexible

resources (Cabinet Gorge, Noxon Rapids, Long Lake , Mid Columbia contract hydro, and theRathdrum Combustion turbines) are dispatched. Even with these resources , Avista still must

purchase peak energy products to meet customer demand during different times. The market

today tends to offer standard heavy load hour and light load hour products that do not meet loadshaping or following needs.

2004 Study

A detailed tabulation of the load and resource requirements study of the year 2004 is alsoattached (see Appendix E). We chose the year 2004 for an in-depth study because, as mentioned

above, many of the larger supply and requirements contracts have ended and future requirementschange (for the most part) due to load growth.

This study is shown in two parts. The first study shows on and off peak loads and resourcerequirements monthly under critical and normal hydro conditions. The second study goes into

even further detail. We created an hourly Surplus-Deficiency duration Curve for the year 2004using PROSYM to gain the following information. By using the Northwest Power Pool' s sixty

year hydro generation study for our system, PROSYM runs 720 (sixty years X 12 months/year)hydro scenarios into the forecast net system load, all known contracts, and existing resources.The information gained from this model output shows the company s resource requirements to

meet load under many different hydro conditions. This duration curve will be used to analyze

how new resource additions will "fit" into the company s requirements without any affect from

market conditions. As stated before , standard economic modeling must be performed afterdispatch information is gained from PROSYM modeling.

Load growth expectations based on the forecasted methodologies are explained under Section A vista doesn t expect drastic changes in our load beyond the nonnalload growth that has been

experienced. But the future is uncertain and A vista needs to be flexible enough to handleunforeseen changes. For example , the company could lose load by having Avista s larger retail

customers install cogeneration, like WSU or Potlatch deciding to serve their own load fromexisting generating facilities. Or if partial deregulation was to come to our region, A vista could

pick up some industrial loads thereby increasing the load requirements.

A vista Corp - 1997 IR.P UDdateExhibit EPage 3 of 5

...

0'10'1

...

ell

. ,...

Exhibit EPage 4 of 5

Exh

ibit

D -

Ann

ual L

oad

and

Res

ourc

e Fo

reca

st

AV

IST

A C

OR

P.

Req

uire

men

ts a

nd R

esou

rces

figur

es in

MW

2000

2001

20

0220

0320

0420

0520

0620

0720

0820

09line No.

RE

QU

IRE

ME

NT

SA

vaA

vaA

vaA

vaA

vaA

vaA

vaA

vaA

vaA

va

Sys

tem

Loa

d15

5710

0815

9410

1315

5797

115

7298

216

0810

0716

4910

3316

9210

5917

4310

9117

9611

2418

5111

59

Pac

iliC

orD

Exc

hana

eP

uaet

#2

I10

0P

acifi

Cor

o 19

94P

GE

#1

150

150

150

150

150

150

150

150

150

150

Sno

hom

ish

10 v

r10

010

010

010

010

010

010

0

Coa

entr

ix 5

7 m

o10

010

010

0N

icho

ls P

umpi

naWest Kootenay

125

Eua

ene

Wat

er &

Ele

ctric

PG

E S

ale

IP

end

Ore

ille

Mon

tana

Sal

e10

010

010

0D

uke

Sal

e I

100

100

100

Cla

rk2

PU

D25

013

725

0C

ity o

f Che

ney

Res

erve

s I

249

246

ill25

126

42Z

.Q

TO

TA

L R

EQ

UIR

EM

EN

TS

2871

1662

2737

1470

2086

1096

2069

1082

2109

1107

2154

1133

2201

1159

2157

1103

2216

1127

2276

1162

RE

SOU

RC

ES

Sys

tem

Hvd

ro93

631

393

631

393

631

393

631

393

631

393

631

393

631

393

631

393

631

393

631

3

Con

trac

t Hyd

ro19

519

519

519

519

519

514

014

014

014

0

Can

Ent

Ret

urn

Smal

l Pow

erC

oaen

erat

ion

Nor

thea

st C

Ts

Rat

hdru

m C

Ts

176

176

176

176

176

176

176

176

176

176

Pac

ifiC

orp

Exc

hana

eB

PA

lAvi

sta

Exc

hana

eE

ntitl

emen

t & S

uppl

emen

tal

BP

A R

es. E

xcha

nae

149

149

149

149

149

149

BPA

-WN

P #3

CSP

ET

rans

Alta

-Cen

tral

ia20

013

820

014

320

014

320

014

3T

herm

al-

Ket

tle F

alls

Col

stri

D22

219

122

219

122

219

122

219

122

219

122

219

122

219

122

219

122

219

122

219

1

SEM

PRA

BP

A 5

yr.

Pur

chas

e11

511

511

5Id

aho

Pur

chas

e10

010

010

0Duke Purchase

100

100

100

MIE

CO

Cin

ergv

Ser

vice

s. In

c.E

nera

v S

ervi

ces.

Inc.

Enr

onT

OT

AL

RE

SO

UR

CE

S24

7614

2524

4212

6720

4094

420

3993

318

2278

918

2278

517

7178

918

7486

618

7486

618

7486

1

SU

RP

LUS

CD

EF

ICIT

T39

523

729

520

315

214

928

731

833

234

843

037

028

323

734

226

140

230

1'"

'd

~ ~

!JQ

=-

1000

'

th :=

:

S, ~

Avi

sta

Cor

p -

1997

IR

P U

pdat

e

EXHIBIT F

Letter of Intent


Avilta Corp.

1411 fa.Mission PO Box3727

Spokane, WaahingtOn 99220-3727

Telephone D" IXSOO

ToDFree &727-9170 .J.' ~'VISTA.COrp.

June 24, 2004

Mirant Oregon, LLCc/o Mirant California1350 Treat Blvd., Suite 500Walnut Creek, CA 94597Attn: Anne M. Cleary, President

Dear Ms. Cleary:

Enclosed please find two signed originals of the Letter of Intent for the potential purchaseof Coyote Springs Unit 2 from Mirant Oregon, LLC. Please sign both originals andreturn one to me.

If you have any questions, please can me at 509 495-8093 or Ron Peterson at 509 495-8045.

Sincerely,

fr~Steven G. SilkworthWholesale Power Manager

Enclosure

AVISTCorp.

Confidential and ProprietaryJune 25 , 2004

Mirant Oregon, LLCc/o Mirant California1350 Treat Blvd., Suite 500Walnut Creek, CA 94597Attn: Anne M. Cleary, President

Ladies and Gentlemen:

This letter of intent Letter of Intent'

~,

effective on the date when executed by all theParties hereto (the Effective Date

~,

will evidence the current mutual intent, as set forth inArticle I below, of MIRANT OREGON, LLC, a Delaware limited liability company Mirant'and A VISTA CORPORATION, a Washington corporation (tlAvista

~,

with respect to thepotential purchase (the Transaction by Avista of Mirant' s 50% undivided ownership interest,as tenant-in-common, in the Coyote Springs Unit 2 generation facility (the Facility"consisting of an approximately 280 MW gas-fJIed, combined-cycle power plant, in Boardman,Oregon, including Mirant' s undivided ownership interest in certain components shared with theadjacent Coyote Springs Unit 1 generation facility owned by Portland General Electric. Mirantand A vista are sometimes referred to individually as a Party" herein and collectively as theParties. Mirant is wholly owned by Mirant Americas, Inc. ("MAl"). MAl and certain of its

affiliates have filed voluntary petitions for relief under chapter 11 of title 11 of the United StatesCode (the "Bankruptcy Code ) in the United States Bankruptcy Court for the Northern Districtof Texas (the "Bankruptcy Court") and continue to operate their respective businesses as debtorsand debtors in possession.

Attached to this Letter of Intent as Exhibit A is a proposal for the Transaction (theProposal') under which Mirant and A vista are prepared to complete the Transaction if they are

able to reach mutually satisfactory definitive agreements for consummation of the Transactionand if they evidence their willingness to proceed with the Transaction by executing anddelivering those agreements.

The matters set forth in Article I and Exhibit A are not intended to and do not constitute abinding agreement of the Parties to consummate the Transaction. Any such binding agreementbetween the Parties will only arise upon the negotiation, execution and delivery of mutuallysatisfactory definitive agreements and the satisfaction of the conditions set forth therein,including without limitation, the satisfactory completion by the Parties of their respective duediligence inquiries and the approval of such agreements by the Parties ' respective board ofdirectors or other required internal approval, all required regulatory approvals and satisfaction ofcertain requirements of the Bankruptcy Code, including approval of the Bankruptcy Court andany requisite approvals pursuant to MAl' s postpetition debtor in possession financing facility.

Mirant Oregon, LLCJune 2S, 2004

Page 2

The matters set forth in Article II do constitute binding agreements of the Parties.

Article I

Transaction Documents

Definitive Agreements. The Parties will exercise good-faith efforts to diligentlynegotiate an Asset Purchase Agreement with respect to the Facility and such otherdefinitive agreements necessary to accomplish the Transaction (collectively, the"Definitive Agreements

~.

The Parties anticipate that Definitive Agreements, if enteredinto, will include provisions substantially similar to those set forth in the Proposaltogether with such other provisions as the Parties may conclude are necessary orappropriate for the consummation of the Transaction.

No Obligation to Enter. Neither Party is obligated by this Letter of Intent to enter intoany of the Definitive Agreements with the other Party with respect to the Transaction orany other matter.

Article II

Binding Provisions

1. Confidentiality. The Parties agree that this Letter of Intent and the matters identified in itare "Confidential Information" under the provisions of that certain Confidentiality Agreementdated of even date herewith, between Mirant and A vista (the "Confidentiality Agreement'

~,

and

that the terms and conditions of the Confidentiality Agreement remain in full force and effect.

2. Term. Unless extended or earlier terminated by mutual written agreement of the Parties, thisLetter of Intent shall remain in effect during the period from the Effective Date until the earliestto occur of (a) the execution of Definitive Agreements, (b) the date on which either partyprovides the other with written notice that negotiations toward Definitive Agreements areterminated, or (c) July 31, 2004, (the earliest to occur of such dates being referred to herein asthe Termination Date

3. Restricted Dealings. During the term of this Letter of Intent, Mirant agrees not to, andagrees to cause its affiliates and representatives not to, solicit or entertain offers from, negotiatewith or in any manner encourage, discuss, accept or consider any proposal of any other person orentity relating to the sale, acquisition or transfer of Mirant' s interest in the Facility. During theterm of this Letter of Intent, A vista agrees not to, and agrees to cause its affiliates andrepresentatives not to, solicit or entertain offers from, negotiate with or in any manner encouragediscuss, accept or consider any proposal of any other person or entity relating to the sale ortransfer by A vista (or its affiliates or representatives) of all or part of a power generation asset inBoardman, Oregon or within the surrounding 50 miles thereof. In the event that the partiesexecute Definitive Agreements, it is understood that the Transaction contemplated thereby willbe subject to higher or otherwise better offers submitted in connection with a Bankruptcy Courtsupervised auction and sale approval process; provided that such process shall be conducted in

accordance with the procedures set forth in such Definitive Agreements, as more specificallycontemplated on Exhibit A.

Mirant Oregon, LLCJune 25, 2004

Page 3

4. Capital and Operating Expenses. For the avoidance of doubt, the obligations of the Partiesto fund capital and operating expenses of the Facility shall be as provided in the Co-Tenancy andJoint Operating Agreement, dated as of January 1, 2003 between the Parties (the OperatingAgreement"

).

Notwithstanding the foregoing, for the period from the date of this Letter of Intentuntil the closing under Definitive Agreements (provided the Transaction is consummated): (i)any capital expenditures made by Mirant shall be repaid to Mirant in full at such closing, and (ii)any prepaid operating expenditures made by Mirant shall be repaid to Mirant as part of aworking capital adjustment under the Definitive Agreements.

5. Expenses. Each Party shall bear its own costs and expenses associated with negotiating andperforming under this Letter of Intent; provided however, that if the Parties execute DefinitiveAgreements, A vista will be entitled to customary bidding protections and procedures as set forthin Exhibit A. For the avoidance of doubt, the expenses of Coyote Springs 2, LLC, a Delawarelimited liability company (the Project Company associated with negotiating this Letter ofIntent and any Definitive Agreements and the execution of the Transaction (including withoutlimitation the fees and expenses of Heller Ehnnan White & McAuliffe LLP, counsel to theProject Company, shall be borne by the Project Company which shall be funded 50% by Mirantand 500/0 by A vista for this purpose.

6. Approyal. Neither Party shall be bound by any of the Definitive Agreements until (a) suchParty s respective board of directors, or other required internal approval process, shall haveapproved such Definitive Agreements, (b) such Party shall have executed such DefinitiveAgreements, and (c) all conditions precedent to the effectiveness of such Definitive Agreementsshall have been satisfied, including without limitation any conditions precedent relating to (i) theobtaining of any and all requisite federal, state or local regulatory orders, consents or approvalsand (ii) payment by Mirant of its outstanding obligations pursuant to the Operating Agreement.Without limiting in any manner the foregoing, the Parties acknowledge and agree that in noevent shall either Party be obligated to proceed with the Transaction, and that each may, prior tothe execution and delivery of such Definitive Agreements , decline to proceed with theTransaction in its sole discretion.

7. Entire Agreement. The binding portions of this Letter of Intent, together with the Proposalconstitute the entire agreement of the Parties relating to the subject matter hereof and supersedeall prior discussions, agreements or understandings, whether oral or written , relating to suchsubject matter. There are no other written or oral agreements or understandings among theParties with respect to the Transaction. Any waiver of any term or amendment of this Letter ofIntent must be written and signed by both Parties. The binding provisions of this Letter of Intentmay not be waived except in writing by the Party who has the right to enforce such provisions;provided. however, that Paragraphs 6, 9 and 12 may not be waived under any circumstances. Nofailure to exercise, no delay in exercising, and no course of dealing or trade custom with respectto, any provision of this Letter of Intent shall be deemed to waive any such provision.

8. Governing Law. This letter of intent shall be governed by and construed in accordance withthe laws of the State of New York, without giving effect to conflict of laws principles.


Page 4

9. Non-Inclusive; Non-Binding. Neither this Letter of Intent, the attached Proposal, nor anyother proposal, correspondence or course of dealing identifies all matters upon which agreementmust be reached in order for the Transaction to be completed or for any Definitive Agreements tobe finalized and executed. Except with respect to the obligations of the Parties expressly setforth in Article IT, this Letter of Intent does not create and is not intended to create a binding andenforceable contract between the Parties as to the Transaction or any obligation to enter into orproceed with the Transaction, and may not be relied upon by a Party as the basis for a contract byestoppel or otherwise with respect to any matter. A binding commitment with respect to theTransaction can only result from the execution and delivery of Definitive Agreements.

10. Assignment. Neither Party may assign or otherwise transfer its interest in this Letter ofIntent without the prior written consent of the other Party.

11. Relationship of the Parties. The Parties shall not be deemed in a relationship of partners orjoint venturers by virtue of this Letter of Intent, nor shall either Party be an agent, representative

trustee or fiduciary of the other. Neither Party shall have any authority under this Letter of Intentto bind the other to any agreement or obligation.

12. Limitation of Liability. UNDER NO CIRCUMSTANCES SHALL EITHER PARTYHERETO BE LIABLE FOR CONSEQUENTIAL, INCIDENTAL, PUNITNE, EXEMPLARYOR INDIRECT DAMAGES , LOST PROFITS OR OTHER BUSINESS INTERRUPTIONDAMAGES, WHETHER BY STATUTE, IN TORT OR CONTRACT OR OTHERWISE, INCONNECTION WITH THE TRANSACTIONS CONTEMPLATED HEREBY.

13. Confidentiality; Press Releases. Each of the Parties agrees that, except as required by lawit will not disclose to any person other than its representatives the identity of the other Parties asit relates to the negotiation of the Transaction. Neither Party shall issue a press release or makeany public statement with respect to the Transaction without the prior approval of the otherParty, which approval shall not be unreasonably withheld or delayed.

If the provisions of Article I and Exhibit A correctly set forth our current understandingas to the non-binding nature of our discussions regarding Definitive Agreements, and theprovisions of Article IT set forth our binding agreements with respect to the matters set forththerein, please execute both originals of this Letter of Intent in the space provided below, retain

one fully-executed original for your file, and return one of the other originals to the undersigned.This Letter of Intent may be executed in counterparts, and all such counterparts together shallconstitute but one agreement.

Very truly yours,

VISTA CORPORATION

By: ~R.

Name: Ronald R. PetersonTitle: Vice President Energy Resources


Page 5

Acknowledged, Agreed to and AcceptedthiS 12!: day of J:&Re, 2004:

~tJ.J- Y

MIRANT OREGON, LLC

By:Name: Anne M. ClearyTitle: President

Exhibit AProposed Terms and Conditions

1. Purchase Price. The Purchase Price for Mirant' s 50% undivided ownershipinterest, as tenant-in-common, in the Facility will be in theform of a cash payment by A vista to Mirant in an amountequal to US$62,500,OOO.OO in immediately available fundsto be made at closing.

If Mirant agrees to sell, and Avista agrees to buy, Mirant'50% ownership interest in the Project Company as part ofthe Transaction , Mirant and A vista will agree upon amutually acceptable price.

2. No Financing

Contingency.A vista has ample funds available to support its offer;accordingly, A vista s offer is not subject to any financingcontingency.

4. Closing.

Upon completion of due diligence and execution ofDefinitive Agreements, A vista shall deposit into escrow witha third party custodian reasonably satisfactory to Mirant anamount to be agreed that will be in immediately availablefunds (the Deposit"

).

If the Transaction is consummated,the Deposit shall be applied as a partial payment of thePurchase Price. If the Transaction is not consummated forany reason (other than due to a breach by A vista of theDefinitive Agreements that leads to termination of theDefinitive Agreements in accordance with their terms), theDeposit shall be refunded to A vista.

Subject to, among other things, receipt of any required third-

party, governmental or other regulatory approvals andsatisfaction of Mirant' s outstanding funding obligations, any, pursuant to the Operating Agreement, it is anticipatedthat the transaction could be closed within 45-60 days of thedate that a motion is filed by MAl andlor its debtor affiliateswith the Bankruptcy Court seeking appropriate approval ofthe Transaction. Closing shall occur within 5 Business Daysafter all conditions precedent have been satisfied.

3. Deposit.

5. Approvals Avista shall be responsible for filing all necessary Hart-Scott-Rodino ("HSR"), Federal Electric RegulatoryCommission ("FERC") and Oregon Energy Facility SitingCouncil approvals. Mirant shall use commercially

6. Related Transmission

Agreements

7. Timing


reasonable efforts to assist A vista in obtaining all regulatoryapprovals. MAl and Mirant shall use their commerciallyreasonable efforts to obtain Bankruptcy Court approval oforders, both in fonn and substance acceptable to Avista, (a)approving bidding protections and procedures, as describedin paragraph 7 hereof, and (b) authorizing the consummationof the Transaction, each within the time periods prescribed inthe Definitive Agreements.

It is understood that the power transmission agreementslisted on Annex I hereto are currently held by MAl or itsdebtor affiliates for the benefit of Mirant' s 50% interest inthe Facility. The parties agree that, to the extent possible andeconomically practicable, MAl or its debtor affiliates willtransfer or assign such agreements or otherwise makeavailable such power transmission service as part of theTransaction. The parties recognize that any assignment ofsuch agreements may require (i) the filing of a motion byMAl and/or its debtor affiliates with the Bankruptcy Courtfor approval of such assignment and (ii) FERC approval. Theparties further agree that to the extent possible andeconomically practicable, MAl or its debtor affiliates willtransfer or assign any requests MAl or its debtor affiliateshave pending for long-term transmission service from theBonneville Power Administration or other transmissionproviders.

The Parties anticipate that the Transaction will be subject tohigher or otherwise better offers submitted in connectionwith a Bankruptcy Court supervised auction and saleapproval process (Parties shall consider jointly whetherauction process will be run through the Bankruptcy Court).Accordingly, the Parties anticipate the following steps in theTransaction:

Execution of this Letter of Intent;

Negotiation and execution of mutually acceptableDefinitive Agreements;

Filing of motion by MAl and/or its debtor affiliates withthe Bankruptcy Court to seek approval of the Transactionand customary bidding protections and procedures,including without limitation, customary overbidprotections and payment of a termination fee expected tobe in the range of 2-3% of the Purchase Price (the

8. Approval of Third Person

Purchaser

9. Documentation.

SE 2019101 v46/25/04 11:04 AM (25994.0009)


Termination Fee ) and payment of A vista s reasonablefees and expenses up to a cap to be agreed, includingattorneys fees and expenses, in certain specifiedcircumstances to be defined in the DefinitiveAgreements; rovided, that in the event the auctionprocess is not ron through the Bankruptcy Court, theparties will provide for such bidding protections andprocedures in the Definitive Agreements.

Filing of all requisite regulatory approvals, includingwithout limitation Hart-Scott-Rodino flling, FERC filingand approval from the Oregon Energy Facility SitingCouncil for permission to transfer the Site Certificate.

It is understood, that if in accordance with the proceduresreferenced above Mirant' s interest in the Facility is to betransferred to a person other than A vista, such transfer shallbe to a third party that meets certain minimum qualificationssubstantially based on those set forth in the definition of aThird Person Purchaser in the Operating Agreement and asMirant and A vista shall agree otherwise in the DefmitiveAgreements.

It is anticipated that the Transaction will be subject to thesame basic documentation that similar transactions betweenthe parties or their affiliates have used previously. Mirantand A vista acknowledge and agree that neither party mayretain Heller Erhman White & McAuliffe LLP in relation tothe Transaction, however Heller Erhman White & McAuliffeLLP may be retained solely by Coyote Springs 2, LLC forassistance in providing form documents and in seekingappropriate approvals (including those set forth in paragraph4 of this Proposal) and the Project Company shall beresponsible for Heller Ehrman s fees and expenses. BothMirant and A vista shall retain separate counsel to assist andadvise on the Definitive Agreements and the Transactiongenerally.

EXHIBIT G

2003 Integrated Resource Plan Excerptsre Preferred Resource Mix


V'STII~

...

~~r

Corp.

':\

Exhibit GPage 1 of 2

The Preferred Resource Mix

Based on the conditions and limitations listed above, the LP Module determined a preferred mixof new resources to meet the Company s future requirements. The Preferred Resource Strategy

includes the following mix of resources and quantities during the first ten years of the study(2004-2013):

149 aMW of CCCT25 aMW of wind197 aMW coal40 aMW of SCCT

By the end of the first ten years, a total of 411 aMW are developed. A depiction of the PreferredResource Strategy is included in the following graph. Significant annual deficiencies do notdevelop until 2008 , so the chart details only the years 2008 through 2013.

ca 300

en 250

:i:Q) 200

~ 150c:C

100

Chart 7.Preferred Resource Mix (in aMW)

2008-2013

450

4000 CCCT

. Wind

13 Peakers

. Coal

350

2008 2009 2010 2011 2012 2013

After 2013 , only coal is selected as a result of a change in the relationship between natural gasand coal prices. Natural gas prices over the IRP term increase faster than coal , making coal

generation less costly in later years. In total , between 2014 and 2023, an additional 566 aMW ofcoal resources are selected in the Preferred Resource Strategy.

Costs of Preferred Resource Strategy Versus "No Additions

. ,

Expected cost over the IRP term has traditionally been the benchmark of least-cost planning; andgenerally includes capital recovery, operation and maintenance, fuel, and transmission costs.This IRP continues to focus on expected power supply cost on a net present value (NPV) basis.Under No Additions where no resource acquisitions are made, the ten-year NPV of the power

Section 7 Page 39 Results

Exhibit GPage 2 of 2

EXHIBIT H

August/September 2004 Loads and Resources Position

Application of A vista CorporationCase No. A VU- 05-

Avista Utilities

Long- Term Energy Load and Resource Tabulation (aMW)

2005-2024

. " . '. ,. .

August 13 2004

';' . ,

Exhibit HPage 1 of 4

1000

tr1

~ ~

(JQ =-....

r::r....

So. ::Q

Lon

g-T

erm

Ene

rgy

Loa

d an

d R

esou

rce

Tab

ulat

ion

(aM

W)

CO

NFI

DE

NT

IAL

Las

t Upd

ated

Aug

ust 1

3, 2

004

Not

es

~ .

AV

ER

AG

E L

OA

D &

HY

DR

O P

LA

NN

ING

2005

2006

RE

QU

IRE

ME

NT

SSy

stem

Loa

dC

ontr

act O

blig

atio

ns

Tot

al R

equi

rem

ents

(1,0

08)

(1,0

69)

(1, 0

41)

(1, 1

00)

RE

SOU

RC

ES

Contract Rights.

Hyd

roB

ase

Loa

dT

herm

als

Gas

Dis

patc

h.U

nits

Tot

al R

esou

rces

233

511

234

157

136

.

236

235

131

113

113 .

106

505

481

477

461

460

459

232

236

240

235

234

238

162

157

162

154

162

157

135

1,10

9 1,

010

963

970

961

~~.a

'w

~"ta

.

.'.

!1iJ

.""'-

''.'

. .. ..

'. ".

_ ,".v

~

. -.-

.,.

. .. .

. .."

,.,,-

rJ.l,

't"",

.

,..

':,O

f:!f

k!'.

'i~~~

td""

'f

' .""

"""

""

i~

~ "

""':.

""(

... '

""""

~~

iL_

:~.

",,-.,.

;;A~

;;:i;i

" ..

~",.:

.",

,_

;;i~-

"--'.

CO

NT

ING

EN

CY

PL

AN

NIN

G

Confidence interval

WN

P-3

Obl

igat

ion

Pea

king

Res

ourc

es

!ZJ2

~.rJ

~.,~~

~, ~i~lXm2~!rt J

llti1

1flr

2007

2008

2009

2010

2011

2012

2013

2014

(1,0

63)

. (1,

122)

(1, 0

93)

(1,1

52)

(1,2

37)

(1,2

65)

(56)

(1,2

93)

(1.3

20)

(1,1

26)

(1,1

85)

156)

-..J

f!)

(1,2

13)

(1,1

87)

-..J

f!)

(1,2

44)

(1,2

12)

(1,2

68)

Not

es:

I. Load estimates are fr

om th

e 20

05 lo

ad f

orec

ast (

07- 2

7-20

04)

incl

udin

g th

e fo

reca

st f

or n

et P

otla

tch

load

.2.

Incl

udes

Nic

hols

Pum

ping

and

Can

adia

n E

ntitl

emen

t Ret

urn

cont

ract

s. D

oes

not i

nclu

de W

NP-

3 O

blig

atio

n.3. Average (60-ye

ar)

hydr

o ge

nera

tion

for

syst

em h

ydro

(C

lark

For

k an

d Sp

okan

e R

iver

pro

ject

s) a

nd c

ontr

act h

ydro

(M

id- C

olum

bia)

bas

ed o

n N

WPP

2003

- 04

Hea

dwat

er B

enef

its S

tudy

, mod

ifie

d fo

r da

ily s

pill.

Mid

- C n

umbe

rs r

efle

ct th

e Pr

iest

Rap

ids

and

Wan

apum

con

trac

t ext

ensi

ons

begi

nnin

g in

200

5.4. Includes sm

aU P

UR

P A

con

trac

ts, U

priv

er, E

l Pas

o 20

04-2

006

25 M

W f

lat,

Duk

e 20

04- 2

006

50 M

W f

lat,

Mor

gan

Stan

ley

2004

- 200

6 25

MW

fla

t,E

I Pa

so 2

007-

2010

75

MW

fla

t, B

P E

nerg

y 20

07- 2

010

25 M

W f

lat,

Gra

nt D

ispl

acem

ent,

PPM

Win

d, a

nd W

NP-

3 R

ecei

pt.

5. In

clud

es C

olst

rip a

nd K

ettle

Fal

ls at

fu

ll ca

oabi

litv

, adj

uste

d fo

r m

aint

enan

ce a

nd f

orce

d ou

tage

.6.

Incl

udes

Coy

ote

Spr

ings

2, C

oyot

e Sp

ring

s 2

duct

bur

ner,

Bou

lder

Par

k, a

nd K

ettle

FaUs CT at

full

capa

bilit

Y, a

djus

ted

for

mai

nten

ance

and

for

ced

outa

ge.

7. T

he c

onfid

ence

inte

rval

rep

rese

nts

the

12-m

onth

ave

rage

of

rese

rve

ener

gy n

eces

sary

to e

nsur

e no

mor

e th

an a

10

perc

ent

prob

abili

ty o

f lo

ads

exce

edin

g, a

nd/o

r hy

dro

unde

rper

form

ing,

dur

ing

a gi

ven

mon

th.

8. Represents highest level

of.

pote

ntia

l obl

igat

ion

to B

P A

gen

eral

ly e

xerc

ised

und

er lo

w h

ydro

con

ditio

ns.

9. Includes Northeast and Rathdrum at

full

caoa

bilit

v, a

djus

ted

for

forc

ed o

utag

e an

d m

aint

enan

ce. .

Nor

thea

st is

lim

ited

to 1

, 700

hou

rs o

f op

erat

ion

per

year

,.w

hich

has

bee

n ap

plie

d to

the

peri

od o

f hi

ghes

t typ

ical

mar

ket p

rice

s.

::',(

.

A vista Utilities

Long- Term Peak Load and Resource Tabulation (MW)

2005-2024

, '

September 1, 2004

. O

. .

Exhibit HPage 3 of 4

Lon

g-T

erm

Cap

acity

Loa

d a ~

d R

esou

rce

Tab

ulat

ion

(MW

)C

ON

FID

EN

TIA

L

Last

Upd

ated

Sep

tem

ber

I, 20

04N

otes

2005

2006

2007

2008

2009

2010

2011

2012

2013

2014

PEA

K L

OA

D A

ND

RE

SOU

RC

E P

LA

NN

ING

RE

QU

IRE

ME

NT

SSy

stem

Loa

dContracts Obligations

Tot

al R

equi

rem

ents

(1,5

49)

(170

)

(1,7

18)

.

(1,6

04)

.(1

66)

(1,7

70)

(1,6

37)

(1, 6

83)

(1, 7

23)

(166

(166

)(1

61)

(1, 8

03)

(1, 8

49)

(1, 8

84)

(1,7

79)

(161

)

(1,9

40)

(1,8

13)

(1, 8

64)

(1, 9

03)

(15 9)

(15

9 )

----

ill2)

(1,9

72)

(202

3) (

2,06

2)

(1, 9

45)

(159

(2, 1

04)

RE

SOU

RC

ES

Con

trac

ts R

ight

sH

ydro

Res

ourc

esB

ase

Loa

d T

herm

als

Gas

Dis

patc

h U

nits

Pea

king

Uni

ts

Tot

al R

esou

rces

r1;~

!;E

Q~I

J'J!

i)l

212

212

215.

215

216

215

108

101

093

093

039

032

001

979

992

991

275

275

275

275

275

275

275

275

275

275

171

166

166

170

166

166

171

166

166

170

243

243

243

243

243

243

243

243

243

243

008

997

992

996

939

932

786

761

774

777

IIB

~)M

, '

RE

SER

VE

PL

AN

NIN

GPl

anni

ng R

eser

ve M

argi

n

~SE

R~E

~~llQ

S.~=

"'"o

".,

(245)

(250

) (2

54)

~)t.'

flf~

~~~'

\1~f

~5~)

"w""

" Jf~

iit~.

,...l

..f~

~,.

""...

.,. 1..

Not

es:

All

data

bas

ed o

n m

onth

ly p

eak

defi

cits

fro

m p

erio

d N

ovem

ber

thro

ugh

Febr

uary

. 1.

Loa

d es

timat

es a

re f

rom

the

2005

pea

k lo

ad f

orec

ast (

07- 2

7-20

04)

incl

udin

g th

e fo

reca

st f

or n

et P

otla

tch

load

.2. Includes Nichols P

umpi

ng, C

anad

ian

Ent

itlem

ent R

etur

n, a

nd' P

G,E

Cap

acity

con

trac

ts.

3.~

eak

hydr

o ge

nera

tion

for

syst

em h

ydro

(C

lark

For

k an

d Sp

okan

e R

iver

pro

ject

s, e

xclu

ding

mai

nten

ance

) an

d co

ntra

ct h

ydro

(M

id- C

olW

J.1b

ia, i

nclu

ding

mai

nten

ance

).

, .. ;

Mid

- C n

umbe

rs r

efle

ct th

e Pr

iest

Rap

ids

and

Wan

apum

con

trac

t ext

ensi

ons

begi

nnin

g in

200

5.

. .

. .

4. Includes small PU

RP

A c

ontr

acts

, Upr

iver

, El P

aso

2004

- 200

6 25

MW

fla

t, D

uke

2004

- 200

6 50

MW

fla

t. M

orga

n St

anle

y 20

04- 2

006

25 M

W f

lat,

El P

aso

2007

- 201

0 75

MW

fla

t, B

P E

nerg

y 20

07- 2

010

25 M

W f

lat,

Gra

nt D

ispl

acem

ent,

and

WN

P-3

Rec

eipt

.5. Includes Colstrip and K

eule

Fal

ls. a

djus

ted

for

mai

nten

ance

. 6. Includes 50

% o

f Coy

ote

Spr

ings

2 a

nd C

oyot

e S

prin

gs 2

duc

t bur

ner.

Bou

lder

Par

k. a

nd K

eUle

Fal

ls C

T. a

djus

ted

for

mai

nten

ance

.7. Includes Northeast and R

athd

rum

. adj

uste

d fo

r m

aint

enan

ce. . .

. .

8. Includes 10% of peak lo

ad (

to a

ppro

xim

ate

load

var

iabi

lity)

and

90

MW

(to

app

roxi

mat

e th

e ri

sk o

f ri

ver

free

ze-u

p an

d pa

rtia

l for

ced

outa

ges)

.

I-d t;r:j

= ~

(JC

=-

~ -

.,&

:.. - .

f"'t"

S, ==

,&:..

, (

= ~

CIJ

tD

=2 n

= a

~ g

~ ~ I ~

~ ~

I _.

CIJ

UI ~

I =

,...

........

CIl.... .

CIl

. I

......

rIJ.

rIJ.

trj

~ ~

!1Q

::r

..,.

..,.

f""I

o-0

~

Value Analysis

AURORA was utilized to dispatch 50% of Coyote Springs 2 (including the duct burner) against20-year sets of fiXed hourly market prices starting in 2005, as described further below.AURORA incorporated the plant s dispatch characteristics (e.g., minimum up time) to simulate

hourly operation and ultimately determine the value of the resource versus each set of marketpnces.

The electric and natural gas prices utilized in AURORA were initially based on monthly forwardprices taken from NUCLEUS on April 8, 2004. These prices were shaped hourly based on prices

from the 2003 Idaho General Rate Case. The resulting prices matched forward prices on amonthly basis, but retained the hourly shape from the rate case. Electric and natural gas prices

were tied directly to NUCLEUS fo~ard prices through 2008, and escalated at 3% thereafter.

Numerous price scenarios, representing potential future spark spreads , were then created and

used as input prices for individual AURORA runs. Spark spread modifications wereimplemented through changes to natural gas prices. Ultimately, four scenarios were used torepresent likely potential futures. These scenarios are described below:

1. Increasing Spark SpreadIn this scenario spark spreads increased over time. Electric prices increased at 3% whilenatural gas prices increased at 2% through the end of the study. This resulted in a gradual

increase in the spark spread through 2024. The resulting average spread was 9,453 BTUIkWh,

growing from 8,572 in 2005 to 10,346 in 2024. This scenario was designed to reflect a market

where electric prices are rising faster than gas prices.

2. Forwards/IRP Spark SpreadSpark spreads in this scenario were tied to forward prices through 2008. .After 2008, annualspreads were matched with those from the 200.3 Integrated Resource Plan (IRP). The averagespark spread for this scenario was 10,928, growing from 8, 165 in 2005 to 12,476 in 2024.

This scenario was designed to capture the most expected short and long-term prices. Forward

prices were used because they represent the actual prices available for purcha~es in the current

forward market. IRP prices were used because the IRP included significant analysis toestimate long-term market conditions.

3. 10,500 Spark SpreadIn this scenario the annual spark spread was set to 10,500 for the duration of the study. Aswith the other scenarios, the spread still maintained the monthly shape inherent in theforwards. This scenario was designed to represent a market where a cccr would be

marginally cost-effective through the entire duration of the study.

4. IRP PricesSpark spreads in this scenario were taken directly from the 2003 IRP. The resulting averagewas 12,482 BTUIkWh. This scenario effectively compares the plant against the avoided coststhat have been established for PURP A contracts

I For the purposes of this document, the term "spark spread" is used to describe the heat rate implied by therelationship between natural gas and electric market prices. The spark spread for a given time period is theelectric price divided by the natural gas price muitiplied by 1,000 (e. , $45/ $5 * 1000 = 9000 Btu/kWh).

Exhibit IPage 2 of 22

The results for each scenario were adjusted by two factors. First, $2 rpillion per year was added

as an estimate for the value of the optimization of turbine fuel purchases through "heat rate

swaps" (transactions in the forward gas and electric markets to either buy fuel for the plant andsell power or sell fuel from the plant and buy the power, depending on the spark spread). Next,

margins generated by the plant during Q2 ,of each year through 2008 were removed to represent aconservative possibility that transmission may be restricted during certain periods in that quarter. Transmission issues are further detailed later in the document.

The results for each scenario were input into a revenue requirements model and a marginalbenefit value, compared to the breakeven purchase price, was determined. 'Refer to the following

table for the detailed results.

Table 3 - Detailed Scenario Results

~m~

Scenario 3parkSpread BaseValue . W/OptionValue

~;

W/OQ2Tra0s'3iBtulkWh) ($000) 1 ($/kW) ($000) ($/kW) , ($000) 1 (S/kW)

Increasing Spark 9,453 21,322 150 46,144 324 46,159 324

Fbiwa,rds/IRE: Sparki:

:: .:::::~::::::?::::::::;:::::

:::lO~92S.:::: ::

: .: .:::

4:3;:164::::: :::;:

;:::

30:3:;:~:

. ;::.::::::;::.

Q7~98:p~::

:;::;:::::::

::::A'78:::::

:::::::;:::.

p7:~9PQ::~: m::;Hm~4A1.

&;:;~

10,500 Spark 10,500 45,633 321 70,455 495 70,471 495

.m::~t: :!::;:~::~);::::::l;:;:;~:IRE:::edce~)i: .;H/~::::::

:::

:::k:::: 12;:482:::::I:::: ;: 92.~:i:ot:

(: :::.?:::::

641E~ ::Y9l:1.p~92~;:;:: ;W~W::ti822::::: :;:;::;llG:~3:a.~~m :m~f~;jm:i~:!~6::1$;~!

(1) Value taken directly from AURORA model runs.(2) Includes estimate of $2 million for value of heat rate swaps.(3) Assumes no generation during Q2 through 2008.

" ,

The second scenario, "Forwards/IRP Spark," was determined to be the most expectedrepresentation of future market prices because it incorporates the best representations of short-term and long-term market conditions. Forward prices, because they represent actual prices for

gas and electricity in the cUrrent forward market, are the best representation of short-term prices.

But since forwards are only available for two to three years out, they are not adequate to representlong-term market conditions. The 2003 IRP, on the other hand, incorporated significant analysisutilizing the AURORA model to estimate long-term market conditions.

As shown in Table 3 above, the resulting breakeven market value for 50% of Coyote Springs 2was roughly $68 million.


* Note: See CS2 Acquisition of Second Half - 2004 , Book 2, tab labeledOption Value Back-Cast Analysis" (9-24-04) for a description of the option

value analysis

' .( .. ' . ,


. .

Coy

ote

Spri

ngs

2 B

alan

ce o

f Pl

ant A

naly

ses

Scen

ario

Heat Aate

Base Value

W/ O

tion

Val

ueW /0 02 Trans

(Btu

/kW

h)

($00

0)($

/kW

)($

000)

($/k

W)

($00

0)($

/kW

)In

crea

sing

Spa

rk45

332

2.1

5014

432

415

932

4Fo

rwar

ds/lA

P Sp

ark

928

43, 1

6430

398

647

896

647

81

O~OO Spark

. 19,

500

. 45

633

321

455

495

70~

4 71

495

lAP

Pric

es. 1

248

210

164

711

6~2

382

211

638

581

8

Scen

ario

Des

crip

tion

Incr

easi

ng S

park

Forw

ards

!.1

AP

Spar

k500 Spark

AP

Pric

es

Spa

rk s

prea

d gr

ows

afte

r fo

rwar

ds -

ele

ctric

pric

e.escalates at 30/0, g

as a

t 20/

0.S

park

spr

ead

base

d on

forw

ards

thru

200

8, t

hen

b~se

d on

2Q

03 I R

P.

Ave

rage

spa

rk s

prea

d ha

s be

en in

crea

sed

to 1

0,50

0 B

TU

/kW

h.E

lect

ric a

nd n

atur

al g

as p

rices

are

bas

ed o

n 20

03 R

P.

* In

clud

es c

onse

rvat

ive

estim

ate

of $

2MM

. for

val

ue o

f hea

t rat

~. s

wap

s.**

Ass

umes

no

tran

smis

sion

is a

vaila

ble

durin

g 02

thro

ugh

2008

.

(JQ =-....

UI C"

... .

f""I

'-

-. t-

I05

- 07

-200

4JR

F

trj

= ~

t'D .,

.. 0'"

0'1

.,..

Q t*

,-"-

. .

Ele

ctri

c an

d N

atur

al G

as P

rice

s U

sed

for

500/

0 C

52 A

naly

sis

Incr

easi

ng2.

park

Fwd/IRP Spark

500 Spark

IRP

Pric

esY

ear

Ele

cG

asIH

RE

lec

Gas

IHR

Ele

cG

asIH

RE

lec

Gas

lliB

2005

42.

572

42.

165

42.

451

34.

603

2006

42.

119

42.

606

42.

010

36.4

218

420

0742

.62

942

.. 8

064

42.

328

38.

124

2008

42.

653

42.

010

42.

10,2

5442

.41

713

2009

43.

944

43.

4.46

795

43.

494

46.

4.48

336

2010

44.

032

44.

394

44.

10, 4

9849

.10

,946

201.

146

.12

646

.10

, 955

46.

4.41

497

52.

070

2012

47.

212

47.

371

47.

500

55.

812

2013

49.

298

49.

289

. 49.

10,4

9957

.48

11,7

4520

1450

.39

050

.65

450

.49

658

~29

879

2015

52.

484

52.

4.43

768

52.

501

59.

751

2016

53.

577

53.

4.59

702

53.

500

62.

906

2017

55.

666

55.

917

55.

500

64.

091

2018

56.

756

56.

807

56.

5.43

498

64.

685

2019

58.

852

58.

037

58.

499

66.

11,9

7120

2060

.95

160

.48

12,2

5860

.48

502

69.

123

2021

62.

053

62.

060

62.

10,4

9970

.89

220

2264

.10

,148

64.

744

64.

501

71.2

495

520

2366

.6.

4525

066

.47

866

.50

275

.19

320

2468

.34

668

.5.

4547

668

.05

6.48

500

245.

663

CS2

Sce

nari

o Pr

ices

.xls

May

7, 2

004

JRF

Rate Impacts

AD. analysis was performed to determine the rate impacts of the selected scenario at variouspurchase prices. The table below shows the estimated rate impacts for the breakeven price of $68million, based upon the "PorwardslIRP Spark" scenario and the purchase price of $62.5 millionthat was negotiated as a basis for the non-binding letter of intent to purchase the second half ofthe Coyote Springs 2 project.

Table 4 - Estimated Rate Impacts

2005 9,849 2.2% 8,847 2.0% .

:t2;Q()Q::ii: :i~::~t::::A:\m~$:igl~:t: ,%';UJW~,%:r :;::mW~:i~imt:9:~~'4:$f: /~:::;U:W~~~$tt~~~t

2007 9,467 1.9% 8,533 1.8%

~::~ZOQ:$!d :m~~i:~:Wj::t:;QW3:f:i:a:n ~%iW:l;i9%B;. #W!~Wi~fij::a~4p.&~TI:~;(~::~~::~m~~4~t%ji:.

2009 3,582 0.7% 2,715

20:tPY:: :~M:~~~~~fimt~47()::6 ::::m:m~)3:~/::m!~:jM~!:n~~~:::: ()35.':~:M~~jNj~():i~f(fl~:r~12011 (587) - 1% (1,391) - 2%

!~:~Q$i2.m: %df:m;~t(2;AQ4)m!: Hm;::~o;4?r4~::. :mj:;~i;::m~~;~llQ):m; :::~:!~~::im:BQt$$.:)J;,

, 2013 (2 860) - 5% (3,605) -Jt~;~Q:t4W~: i~!~1Wjt~:(~~5$~~:~~WMQ17i%.~: ~~~j~:;!~fj::~($j;~!"Plt~~ ~n~~;m;%MQ;:al't.~t~

I 2015 (5,647) - 8% (6,334) - 1.0%

jj:;i~():XiQ~f ii51il~~W~'€)t$Q41% ~r!;~~Q~~q~~1, :;i*m~J~!lli:tq~~:()g);~~: Will~~~~~~:~Plr4~

2017 (7 644) -1.1% (8,273) - 1.1%

~\ifj~p:Ji;a::m ~~illWm~;1~($.~X$:lDjlli: ;~\~#:l~~li%'~. :l :~*;~lfWJfTh:6$!~7:$~1~mi! ~$t%~'

2019 (9,655) -1.2% , (10,226) -1.3%

;i~i~Q~()j:;j ;illiit~~Wf~;)$!~2.$i$J1~ iif;l;tJ:;f1?r.~1'i' 4mfj%~i~~,:~t;q:$QJlj~: m~M;mm*:~i1:~$;o/.~~~

2021 (11,466) -1.4% (11,979) -1.4% .

m::;~Q~~::;/n::~::::(lih3$4:)~!::: ~:;~:,:Rl;::3:;o/q:m :~WiiimW.(:~!;~i;$~:alf!;::j~;~~i~~~:::~~~j;~:~4~t

2023 (14 595) -1.6% (15,050) - 1.7%

::j;2Q2.4::: :C:::t' ~(l5\63;6Yi: mim:.~l'ili6J~J::: ::;:::jj;

:::;::

(t6'; Q62):::::;:::;~:m::i:~fJ;W7::%J~:"


Yea

r20

0520

0620

0720

0820

0920

1020

1120

1220

1320

141

2015

2016

2017 01

820

1920

2020

2120

2220

2320

24

20

Yea

rsY

ears

.

SMM

($43

9/kW

)$S

3MM

($3

75/k

W)

$71

MM

($5

00/k

W)

$1 0

7MM

($7

50/k

W)

.($0

001

Jper

cent

.lJp

erce

ntl

1$00

0)Jp

erce

nt.l

1$00

01Jp

erce

ntl

847

171

60/0

10,4

3130

/016

, 950

80/0

248

625

1 . 2

0/0

781

90/0

093

20/0

533.

80/0

970

1. A %

010

1 %

091

30/0

468

. 1.7

096

110

40/0

890

00/0

15, 7

4871

$50

/026

420

/008

680

/072

91 . 8

0/0

635

1 %

. (763)

1 %

;95

500

4039

130

/039

1)20

/073

7)(1

19)

116

90/0

179)

50/0

(4,4

75)

-0.8

0/0

955)

30/0

087

605)

.85

3)80

/0(2

,427

)0 040/0

2,42

400

40/0

276)

80/0

(6,4

74)

1.00

143)

60/0

518

1 %

334)

(7,4

84)

1.10

/024

8)80

/0(7

75)

-0. 1

%

962)

00/0

064)

1.20

922)

639)

20/0

273)

1.10

/032

6)1 .3

0/0

279)

00/0

185)

0040

751)

1.20

/075

5)1 . 3

0/0

. (7

803)

00/0

898)

50/0

. (10

, 226

)(1

118

1)1.

40/0

(9,3

23)

20/0

608)

70/0

(11

780)

50/0

(12

687)

1.60

/0(1

092

3)30

/039

6)(1

197

9).

-104

0/0

(12

838)

1 .

(11

169)

1 . 3

0/0

830)

90/0

(11

838)

40/0

(12

647)

1.40

/0. (

1107

3)1 .

923)

0~90

/0(1

505

0)-1

.70/

0(1

581

2)70

/0(1

433

1)-1

.60/

0(1

137

0)1.

20/0

(16

062)

:1.7

0/0

(16

775)

1 . 8

0/0

(15

388)

60/0

. (12

615)

1 . 3

0/0

Net

Pre

sent

Val

ues

(20

113)

461

53, 6

0985

599

759

,282

NO

TE

S:

1) In

clud

es c

onse

rvat

ive

esiim

ate

of $

2MM

for

valu

e of

hea

t rat

e sw

aps.

2) A

ssum

es n

o tr

ansm

issi

on Is

ava

ilabl

e du

ring

Q2

thro

ugh

2008

. . .

3) A

ssum

es $

450M

M b

ase

reve

nue

requ

irem

ent ,

esc

Fila

ting

C;W

10

per year.

4) S

park

spr

eads

bas

ed o

n fo

rwar

d pr

ices

thro

ugh

2008

, lA

P pr

ices

ther

eaft

er.

(JC

I =

-(D

_.

co C

'"

- .

f""I

-

.....

05- 1

8-20

04JR

F

. AV

IST

IN I

cAN

AL

DR

AF

T

500/

0 of

C

oyot

e S

prin

gs 2

(C

CC

T .

and

Duc

t Bur

ner)

Eco

nom

ic A

naly

sis

Det

ail

Ass

umpt

ions

Iins

talle

d C

ost

500

2004 $OOOs

Fix

ed C

harg

e0 2004$ per kW

-mo

Insu

ranc

e C

ost

Inst

alle

d C

ost

439

2004

$/k

WF

ixed

O&

M75 2004$ per kW

-mo

Gas

Tra

nspo

rtPr

ojec

t Cap

acity

.14

2.E

scal

alio

n R

ates

Gen

eral

lnfJ

atio

nH

eat R

ate

444

Btu

/kW

hA

xed

O&

Mpe

rcen

tO

ptio

n V

alue

Gas

Usa

ge R

ate

25.

opos

dth

fday

Tra

nspo

rtat

ion

perc

ent

. 187

. 50 2004 $0005

00 2004

$Idt

hfda

y0 percent

000 2004 $0005

Nom

inal

Dis

coun

tR

eal D

isco

unt

2 percent

5 percent

Yea

r 2005

2006

2007

2008

2009

6 2010

7 2011

8 2012

9 2013

10 2014

11 2015

12 2016

13 2017

14 2018

15 2n19

16 2020

17 2021

18 2022

2023

20 2024

Ene

rav

(GW

h)

714.

723.

689.

690.

~09.

880.

929:

194

4.94

1.94

6.94

7.94

9.94

8.94

7.94

9;95

4.94

9.4

946.

951-

954.

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Fix

ed O

pera

ting O

ptio

n N

et Tot

at P

roje

ctPr

oiec

tF

ixed

Chr

Tot

al

ost

Fixe

d G

tran

s Pr

Tax

Insu

r.Total Costs

Cos

ts M

arai

n V

alue

Proect Benefit

otal

Va

iabl

e C

ost

Cos

ts($

000s

) ($

000s

) ($

000s

) ($

lMW

h) (

$000

s) (

$000

5) ($

OO

Os)

($00

0s)

($O

OO

s) ($

lMW

h) ($

0005

) ($

0005

) ($

0005

) ($

000s

) ($

lMW

h) (

$000

5) (

$/M

Wh)

($0

005)

($IM

Wh)

t 1,9

~6 0

. 1i9

~~ . :

:16.

: : .

. :~\

'::'

': .

::;-0

. t':::

:it:~

~~t;?

1~'):

;:J~~

(.:

:.:ri

~a?~

itt(J

($;:

~tiJ

?t:I

?tttP

~M:~

:;~:.)

:::~~

1 ~t

):rt

);p~

~f:: .

::::: ::t

~;~4

.7)/

.::'

::tj~

I4j::

:;C::~

A7~

~)/

l~:~

)4Q

.!~' ::?

fV.:t

:'

~;. ~

?2: .

::.:.:

::: ))

2:8.

11,5

44 0

11.54

4 16

.

. ~! 17~. ...... .

~. ."

" ~~~......... J.

~~...

....

~'.'.

""""

'~"

"'

i"'"

'

~~!!

~~"

....

3~~.... ?~

?? ..

..

.F! ~

~~L

....

C?.o

.) ..

....?!

!~~~

......

......

?.... ..

~~, 3~

1

... ,.. fj

917

8. .

. 1.

:: 16.~

::::::

:::::~, ~~

~::;~

:'::::

t\::

::::/Q

: cii\

)t::1

,~. ~

:~~l

i:d:~

~q~f

.l::I

A~~

~;tD

~:~~

t~~~

~ij';

:~:;:

~::~

~~';;

:';iM

:~;

AA

1\' ~

:~::~

\:4;7

. ??:

t\:/:

?;i.

~5::::

.:::

:(~;

:3~)

::f:::

;;):

~A) :::)~n~7. ;~

1:7:

:::!t

t:~~r

~Q. ;~

\&M

:::~;

!~:3

;~~

a:::

;:.

:::::

::'

:;Ii!

~;~

: ~::;

: ~.

:ij;~

~:..

' :~

:~ ;;

g1~;

~;l%

Win

~ wMwJiji\\J*$~i%tt~j;r;4?'k~j~'$Jii\ti~:~;i ;&t;~~~5W1~;li~; .

yI~:

if::1

$3ij~

j~j g

~~j4

;mt$

i\*i;t

Wtm

M;T

h~lt5

;:~:;.

225

. 0 10

~2~... ~.

~....

......

56~.

... ..

....~.

...+

.... ..7

0

,....

~~~.

.....

.._

4~?.

. w""

~,..

......

+...

,... 1~

,?~~

.. .'"

.

6~~.

.. ...

~ ''

.

J63~

.

~~:.!

) .

8.~~

,,".,

.... ~3

.

. ....

6~6 , 50.

a51.

.

: '.

\~, ~p

t'.

:. ..

. : .'l

Q;7

r:r

:

:::::; :3

,~ij7

. ~:::

:~::t

)~:f

:'\::

O: :

::t;::

HtJ

i.7:J

t::~h

::n~~

: 1:J

::~~t

::4~2

-~tt:

: ~~~

A:&

fJ~ !

;H~

;::;~

!;~ft:

:J:4

~~

~?:

:: ':?:J~Aa~ . :::::::

:;

~A~9

/

:::::;

::::: h~

a.r\

/:::;t

:.1.

:~:

:::'~

::.

~9.

'::::\

::':~

~:;~

::.:::

:):.:

::::-

' 4~"4pa :

..

!l8,

65

6 0 9

656

10. 2

3, 7

85

646

238 4

669

4.9 14

325 14

971

. 2534 317

9 3.4 31

324

33. 2 45,

649

48.

103

0 9

103

9.6 401

5 58

7 252 4

855

5.1 13

958 16546 2688. 527

6 5.6 3254

9 34.4 46

506

49.

.~~~

3?'

: .0.

. . :.

832.

: :::.

;:: : ::

9;3.

; .:::

j:;tf

K1:

~~:~

r~:q

~\)j

~:'Q

:PtJ

t~$~

Mtf

\~~p

::I:M

f4fQ

~!fg

\~)K

M~m

Hll~

J~/i~

~:~:

. Jrn

i~~~

l':/J

\.~~;j~

~': :

:::;(

;:

~~ilr

~:I:

4r::~

jj: . ::J

f:~~

' :?i4

:tim

r:~:

$jm

rr;tw

i~Q

~~::t

:;:;r

:

~~. 1;

.58

7 0 8

587

9.0 4260 O

. 529

267 5

056

5.3 13

643

. 17,754 2852 6

962

7.3 34

522 . 36.4 48

164

50.

059

0 8

059

8.5 451

9 0 470

' 284 5

273

5.6 13

332 19058 3025 8

751

9.2 36

240

38. 3 49

573

52.

7 ;7

60

':j~

-;~q

::::

..

., Q

,?'::

::::;'

:/::: ~;

~$~;

:;trt

)::

:rO

\~:::

t:?:h

#f::j

F#t?

~g~N

)tM

~~~f

%H

ft~~

~Mr.

~tt,J

~~t~

~:: ?

mt?

'Q~?

lQ?W

r:;::

~;j:1

~:::;:

. .

/\j:Q

;. ?g~

~:I)

r)(1

:Q~

Q::

: :rl::

~~i~

tijt:I

\I~i

j;QW

~TM

)~:~

;:~~.:

~r

::::'$~

. ::6.:

510

0 7

510

7.9 479

5 41

1 30

1 5,

507

5.8 13

017 21587 3209 11

780

12. 3 37

488

39. 3 50

504

52.

069

0 7

069

7.5 508

7 35

2 31

9 5,

758

6.1 12,828 21261 3405 11

838

12. 5 40

989

43. 3 53

817

56.

489

0 6

489

6.8

5,39

6 29

4 33

9 02

9 ' 12518. 24967 3612 16

062

16. 8 41

552

43. 5 54

070

56.

Net

Pre

sent

Val

ue 9

437

1N

omin

al L

evel

ized

Cos

t ($/

MW

h)R

eal L

evel

ized

Cos

l ($/

MW

h)

tfj

= ~

(JQ =-

~ -

.

\0 9'"

.f"

'I'-

Q ~

371

083

256

327

666

140

037

122

777

822

561

307

192

447

230

11.

35.

28.

52.

42.

02 A

uror

a R

esul

ts (

IRP

tHR

afte

r 08

).xl

sI'l

l: ~

n ...

nn.

,ri.-

- -

""d

tr1

= ~

(JQ =-

(D -.

~ s:

= '*

Q ~

....,

-.,

yote

Springs 2

Rat

e Im

pac

ts$3

6MM

($2

~O/k

W)

$53M M ($375/kW)

$71

M M

($50

0/kW

)$1

07M

M (

$750

/kW

) Y

ear

fiQ

QQ

lIp

erce

ntl

fiQ

QQ

lfp

erce

nt.l

fiQ

QQ

l!p

erce

ntl

fiQ

QQ

lJp

erce

ntl

2005

911

171

1 . 6

0/0

, 10,431

30/0

950

80/0

2006

2,46

950

/062

51 .

781

1 .

093

20/0

2007

929

80/0

970

1.40

/0.

010

1 %

16, 0

9130

/020

0803

396

11.

40/0

890

00/0

748

2009

(1 ,55

7)30

/026

420

/008

680

/072

980

/0 .

2010

(3,4

81)

60/0

(763

)95

50.

40/0

391

1 . 3

0/0

2011

355)

-0.

737)

-0. 5

0/0

(119

)00

/0 .

116

90/0

2012

99

6)1.

20/0

(4,4

75)

80/0

955)

-0. 3

0/0

087

50/0

- 20

1327

8)-1

.85

3)80

/0(2

,427

)0.

4 %

2,42

40.

40/0

..

2014

805)

1.40

/0(6

,474

)00

/014

3)60

/051

81

%20

1572

0)-1

.50

/0(7

,484

)-1

.10

248)

80/0

(775

)1

%20

16(1

020

5)1 . 5

0/0

064)

1 .2

0/0

(5,9

22)

639)

20/0

2017

(11

373)

1 . 6

0/0

(9,3

26)

-1. 3

0/0

279)

-1.0

0/0

185)

0.4

%20

18(1

170

7)1 . 6

0/0

755)

-1.

803)

1 ~

OO

/O89

8)50

/0 .

-201

9(1

303

9)-1

. 70/

0(1

181

)1.

40/0

323)

1 .

608)

-0.7

0/0

2020

(14,

450)

-1.8

0/0

' (12

687)

60/0

(10

923)

396)

90/0

2021

(14

507)

70/0

(12

838)

1.50

/0(1

116

9)1 .

830)

90/0

2022

(14

222)

.(1

264

7)-1

.40/

0(1

107

3)1.

30/0

923)

90/0

2023

(17

293)

90/0

(15

812)

70/0

(14

331)

1 .6

0/0

(11

370)

1.20

/020

24(1

816

1)1.

90/

0(1

6,77

5)80

/0(1

5,38

8)-1

.(1

261

5)

Net

Pre

sent

Val

ues

20 Years

(44,

686)

(20

113)

461

609

Yea

rs71

385

599

728

2

NO

TE

S:

1) In

clud

es c

onse

rvat

ive

estim

ate

of $

2MM

for

valu

e of

hea

t rat

e sw

aps.

2) A

ssum

es n

o tr

ansm

issi

on is

ava

ilabl

e du

ring

02 th

roug

h 20

08.

3) A

ssum

es $

450M

M b

ase

reve

nue

requ

irem

ent ,

escalating

(g)

40/0

per year.

4) S

park

spr

~ad

s ba

sed

on fo

rwar

d pr

ices

thro

ugh

2008

, lA

P pr

ices

ther

eaft

er.

04- 2

8-20

04JR

F.

AV

I5T

'. '

RA

FT

500/

0 ' o

f Coy

ote

Spr

ings

2 (

CC

CT

and

Duc

t Bur

ner)

Economic Analysis Detail

Ass

umpt

ions

Inst

alle

d C

ost

570

2004

$O

oos

Fix

ed C

harg

e0 2004$ per kW

-mo

Insu

ranc

e C

ost

106.71 2004 $ooOs

Inst

alle

d C

ost

250

2004

$Ik

WF

ixed

O&

M75 2004$ per kW

-mo

Gas

Tra

nspo

rt00 2004

$Idt

hlda

yP

roje

ct C

apac

ity14

2.E

scal

atio

n R

ates

General Inflation

0 percent

Hea

t Rat

e44

4B

tulk

Wh

Fix

ed O

&M

0 percent

Opt

ion

Val

ue000 2004 $ooos

Gas

Usa

ge R

ate

25.

OOOs dthlday

Tra

nspo

rtat

ion

0 percent

Nom

inal

Dis

coun

tReal Discount

2 percent

5 percent

Yea

r

1 2005

2 2006

2007

4 2008

5 2009

6 2010

2011

:8 2012

9 2013:

10 2014

11 2015:

12 2016

13 2017

14 2018

15 :.20

1916 2020

17 :2

02f

18 2022

19:2

023:

::'

20 2024

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Fix

ed .

Ope

ratin

g O

ptio

n N

et Tota

l Pro

ject

Ene

rov

Proiect F

ixed

Ch

Total Costs

Fixe

d G

tran

s Pr

Tax

Insu

r.Total Costs

Cos

ts M

aroi

n V

alue

Pro

ect B

enef

it T

otal

Var

iabl

e C

ost

Cos

ts(G

Wh)

($0

005)

($O

OO

S) (

$000

5) (

$/M

Wh)

($0

00s)

($0

00s)

($0

00s)

($0

005)

($0

00s)

($l

MW

h) ($

0005

) ($

000s

) ($

000s

) ($

000s

) ($

lMW

h) (

$000

s) (

$/M

Wh)

($0

005)

($lM

Wh)

: 7.1

4, 2

::::. :::

,:::::

:::'1

j 4

~O

~::

: :::: :::

: :ii:

;::.:,

::~:: ill:::

:;():

:;: ::

::

::

t~45

tt:

:;W:f:

.:: lj

. (f~

:: :;: ~

~r

r:i ~~

~ Q!~

; :~

I~tlK

: %~

ir0;~

t~l*

i: M

~:~~

~1f

f?~\

1J:9

'f~iti

l~: ~

?g~

~~~1

~~JI

B.a

l~~

!~~

~~

ifI j.

~1:

2~:~

~~~~

~trM

1$1 VJi$;? ~p$(tm: .

mK

(~:~

j J)

: :;~

:~:d

fa~

; $)

; gi~

m; ?

~; ?

ij~;m

r&~

~i:M

~ ~

:;:Ji

li~fu

1~:~

~; ~

~~j~

fiif

~E~~

;ij :

:72

3.5 7,20

5 0 7

205

10. 0 317

0 46

8 11

3 3,

751

5.2 10,

956

6,36

5 2,

122

(246

9) (

3.4) 27

606

38. 2 38

563

53.

689

. 3.. ::

: . '1 ; ~

Ot(

:;::::

::::':

::::::

:;:::::;

: ~::::

:: Q

::::::

:.

::: ::;

. tqQ4::r ~

': :i::::

::::; 1. Q

~':

:i:;:

: t::,:

~~: ; ~

~$::

ji~~W

:r: (

:9 :N

:M~

K~

4M~~~%~f&J'J 't:.1r(r~j~J~:;~~~\l~m~r~~~fcl~.

~tfl

~~~~

nQ;

~~t:1

~~~i

&JA

1

??(~

jt ;:I

t?;j

. ~$:

:':. .

m;!

't t ~

~:~

g~r

:'j 2

m?:

l $:

1)

: ::W

:~~

; a:t1

J~~

t~~

N (

j;~F

8~

~iM

:~~

~7:

t4 ~:i~~%i~t$It.

~::

880.9 6,50

9 0 6

509

7.4

3,56

8 0 401

. 127 4,09

6 4.6 10,606 11

699

2,38

8 3,

481

4.0 29

885

33.9 40,

490

46.

. .

: :9.~

9 . 7

: .

:::: :

:::6;

~1t\i ::X: ::~

::::::

::::::

;::?

:9:

, ::t

:;;:::

~ ~?

t%~i

li:~:

y: :$

~ ~

;:~~

:'?H

~; ~

? $;

!:~~

WJ:

~~1t

i:P: j

~W:~

Wl:?

~lf,

~$i~

~f$)

;lli!

rW~J

4:;1

~9l

i~W

~~l~

~;~

t;lill

~lqp

~ $

~~~i

~Jd3

iM~ Uill~Yi~~:Mg:ill;:

::~:~

:$ ~

~$$

:\1f

,1fl~

~t :

;:$ ~

~: ::~

jiJ~9

~~

~~:~

~J~:

~~l ~

;lg~~

1~J~

~' :~

$,Q

4 m

a$~~

:~,tt

:;

~' .

944.7 6,22

0 0

6,22

0 6.6 378

5 36

8 135 4

288

4.5 10,508 14

971

2,534 6

996

7.4 31

324

33.2 41

832

44.

941.

: 4 :

..: : . 6

~ p~

7.

::::::

::::::::::: ~

:::: :i: ::

::::. :

::::: g;

~ J

j~ t.

: m%

:: lE

i: ~

;~::

/:M;::

::~:;

~~ ~

~:~~

1rgi

~Yf1

~~~C

p::g

:i~~~

f:tJ

~~K

~frs

111W

J~~~

#~1~

;ffi

8 ~

~,~'

i~ri

~A~?

iIi';

ZJ.

:llq~

4P,~

::ill~

\t~;~

.Mlrr;:g~; ~1 :9;

~: . ~

~E

~?t

i2i~

~i~

M;:i

ll;l~

t7V

t:: :m

L~.

~1 ~

I ~~

0;~r

li~~h

~~7J

~~li~

.? ;:

a~~i

a1~~

I45/

~::

946.3 5,93

5 0

5,93

5 6.

3 4,

015

334

143

4,49

3 4.7 10,

428

16, 546 2

688

8,80

5. 9.3 32

549

34.4 42,97

7 45

.4

. :. . ~41; 1 : .

:::: :

:::. ':::1

)

~~:':

';::::

:;::;:

'0:: :::/ :

:r:~

: ~o;

: tn~:

~:~;

1~~

.:~n~

t :t~

' :'

: 1: :

~;;

;:mm

:j'~:

J ~

~:~

till~

~:t~

~:9

;~f\~

~~

;~. j

~fi

~~~~

~~l~

ff:~

:~iI

~t~9

:1~$

t4m

~)H

t,~~z

~~~m

1J;)

: ~O

O1.

~m~i

li~l ;

~~v;

mill

;~~~

g;tij

~::; : :B

:K~~

t?Q

g~;:m

lMri

t~:~

:: :~

:;W~~

;gt4

~1JJ

i~m

;~.$

:;:E

~f~~

~" ~~i

~~

;~t

~j;~

?J~~

!i. $

Li;;

:94

9.0 568

7 0

5,68

7 6.

0 4,

260

301

152

4,71

3 5.0 10

400 17754 2

852

10,2

05 1

0.8 3452

2 36.4 44,92

2 47

.

. :: ': : :9

48:

6 . :

:::: :

::::::

:&

:; $~6:

::

\:.: ::

: \/;

t?i:

t t::~

:: /l:

ffiM

; M.~

tMm

:m m

$;~

:: m

~1~~

j~4i

~~~

1~il!

~::tt

9:g~

~&1~

:gM

~*W

i:~~J

~jJ~

~ltJ

fA;,~

g~t~

~i~~

1~~~

~(t~

~1! ~

~M~~

~~1

~;~9

W(~

~I~

r~r~

~?J

:~: :

:r~r

~~ f~~i~l:~~J!in g:;

pi :

:;*E

~4 '~

4?;w

.41~

~~~~

;~i*

f~JM

~MIT

~~~r

i~~~

4 1:

: .94

7.5,

428

0 5

428

5.7

4,51

9 26

7 161 4

948

5.2 10

376 19

058

025 1170

7 12.4 36

240

38.3 46

617

49.

:949

: 1

': :::

::::::::

;::.

2 a:

t:::::

;: :i,

:;: :::: :::

::: ::: ;::

:::;:9

: ~m~

$;'~

~3am

fu::n

;:

:~ ~

Wg:

m~g

: ~

;~M

~;~z

~~ili

~~f~

Wfl

~;~~

~\:g

$Ji:~

mt.~

J~i1

~,~

~r~~

Z~;

'Pi:

~fii~

ii~1 ~

~~;&~!il~1 qi~~$~~~g,P';

~1~~

m(J

)~il~

.m~:

: :m

~~ ~

;9.~

9 :::

1i~f

fi~~

~:;

1: ~

:~~:

: m

~~~ ~$

in

~~~ifi~ ~~; ~

J~ti~

1~I&

I4t.~

j:~

lm~

~t~

~:4

9)t:'

954.0 514

7 0

5,14

7 5.4 479

5 23

4 17

1 5,

200

5.5 10

347

21,5

87 3

, 209 14

450

15. 1 37

488

39. 3 47

834

50.

::: . 9

4g ;

4 :::

:';:: .

::::::

:: : 5; 0

4 n r::n :~

m~:

H

;i:: \ ~

, ct::

:j~: ~:

m:~

;91

t(~i

li;~m

1$

~:&

%tM

;~~~

, M~t

~1~:

q~M

;WJ:

1J1~

1 :li

~iiq

~1j;t

~mt~

~~~

?I!I

WB

l~h~

~ift

~;~

~g~;

iilli?

J; ~

~ ~~

ID!J

~%iE

;~

~~Q

~2 ::

1lli\

) : ~1

~Q

:~i!

;it~:

~~

~:: :

&~~

~1~~

~~ ~

~.mW

l.'~

r~l~

iH11

lWl~

:;~~

:~!ij

;:;i1

~r~

1~g:

9;94

6.7 497

4 0

4,97

4 5.

3 5,

087

201

182

5,46

9 5.8 10,443 21

261

3,40

5 14

,222

15.0 40

989

43.

51,4

33 5

4.

. . 95

1:;a

'

:::: :::

:::i::

: :4~

~ 7:

; ;~

;ii\~

8 :;:

:i:~

:~;m

:;o

:iili ~?

~;:4

. ;7~

7mR

ili~

M~

~Q

:ri~

~~

l~~

;?~

~l~

~~

2~~

lftf~

9;~

mJi

~;H

~~

t;~*~

J,~!

~Wi~

~1~l

Q~~

.$I~

~"~

~j :

9;~

ii'5

t~E

?1~.

1:

~~ ~

~~

~ ';

$Q

iE j

t:~tl~

g~

~:m

~!j~

%tM

~:: :

~~t4

Qi g

Q7j

~ifl

,1 g

:;?J~

~Jti.

~~9;

~~~1

~it~

1t~~

W:

954.7 466

2 0 4

662

4.9

5,39

6 16

7 19

3 5,

756

6.10

,418

24,

967

3,61

2 18

,161

19.0 41

552

43.5 51

~70

54.

102

781

409,

973

Net

Pre

sent

Val

ue 6

081

3N

omin

al L

evel

ized

Cos

t ($/

MW

h)R

eal L

evel

ized

Cos

t ($/

MW

h)

trj

~ ~

(JQ =-

rD -.

0'"

.....

- .

.....

""""

0 ~

....,

60,8

1356

132

496

812

277

724

,822

44, 8

1830

719

208

335

.28

.47

.38

.

02 A

uror

a R

esul

ls (

IRP

IHR

a"e

r 08

).xl

s09

-15-

2004

JR

F

AV

IST

lRA

FT

500/0 of C

oyot

e Sp

ring

s 2

(CC

CT

and

Duc

t Bur

ner)

Eco

nom

ic A

naly

sis

Det

ail

Ass

umpt

ions

Inst

alle

d C

ost

355

2004 $0005

Fix

ed C

harg

e0 2004$ per kW

-mo

Insu

ranc

e C

ost.

160.07 2004 $0005

Inst

alle

d C

ost

375

2004

$/k

WF

ixed

O&

M75 2004$ per kW

-mo

Gas

Tra

nspo

rt00 2004

$/dt

hlda

yP

roje

ct C

apac

ity14

2.E

scal

atio

n R

ates

Gen

eral

lnfl

atlo

ri

. 3.0 percent

Hea

t Rat

e44

4B

tulk

Wh

Fix

ed O

&M

0 percent

Opt

ion

Val

ue000 2004 $0005

Gas

Usa

ge R

ate

25.

OOOs dthlday

Tra

nspo

rtat

ion

0 percent

Nom

inal

Dis

coun

tR

eal D

isco

unt

2 percent

5 percent

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Fix

ed O

pera

ting O

ptio

n N

et Tota

l Pro

ject

Ene

rqy

Proj

ect

Fixe

d C

h rq.

Total Costs

Fixe

d G

tran

s Pr

Tax

Insu

r.T

otal

ts

C

osts

Mar

qin

Val

uePr

oec

t Ben

efit

Tot

al V

aria

ble

Cos

tC

osts

(GW

h) (

$000

5) (

$000

5) ($

0005

) ($

/MW

h) (

$000

s) (

$000

s) (

$000

s) (

$000

5) (

$000

5) ($

lMW

h) (

$000

5) .

($00

0s)

($00

05)

($00

05)

($lM

Wh)

($0

005)

($I

MW

h) (

$000

5) ($

IMW

h)1 ~~ 71~:

JM~~

C&

0~0~

~~D

j5(M

M0~

mB

$3~~

~W~~

~~0'

~mfi

g~IM

~~~

~Wnm

mT

I~ ;~

~ij~

~I~~

~g~~

X2 2006 723.5 10,07

0 0

.10,07

0 13

. 9 3

,170

70

2 17

0 4,

042

5.. 14112 6

365

2,12

2 (5

625)

(7.8) 27

606

38. 2 41,

719

57.

3 20

07. :

689.

3 .

. ":"

., .

:: .

. O.':.:

:::':::

' ~/If

3.1:

:.::::

:t::::

:::1;4

~?'::

:::;~

;: :t3;~

$$;::

~;::M

:bM

:Q::i

:m:~

;;::M

.t:K

1~f~

j;i$;

~r~K

t~;:j

:I'l!

~j, ~

ltt~1

~;9)

irm

r&f(

~::

~ijt~

9~~%

;~iZ

~:;~

:!t:~

tJ::?

;:~;~

$::::

:. .

t:Uf3

~~7i

J)~~

$tH

t9:J

) . \t

l?t:~

fX:;i

Mn:

:~(j

,4:~:

FS~~

::~4t

7Mm

:m~%

5::~

.o;

6 2010 880.9 896

3 0 8

963

10. 2

3,5

68 .0

6.0

2 191 4

361

5.0 13,324 11

699

2,38

8 76

3 0.

9 29,88

5 33

. 9 43,

208

49.

2011

.92

9; 7

. .

;:::: :

:::;:: t8

~ 7~

:(::

::::::

:::::)

i~: :::

:~::~

O:::

::::::

:n;a

, l ~1:

::'(?

mt::

::9~ 4

)!~:

f:/:~

r~;~

1 $;

)~!~

tJ:~

~~i~

:i~9;

::fjf

f~~~

~~~:

i7J~

~~J~

;~:~

:iffi

1!~i

4;M

~~~0

.~'~

~;Q~~~i~~J~~1:~~:~~~%:~~j:~;4~~imrtg~4~9:;:: .:m:!~~::?/t~7~m~ri:iM:r~~~~:\6:~p'~~ij~2~1JV.~1~:~~;~'

5fiW

8:M

~1.?

?:Y

:~~~

:::4!

;;$;.

8 2012 944.7 849

0 0

8,49

0 9.0 378

5 55

2 203 4

539

. 4.8 13

029 14971 2534 4

475

4.7 31

324

33. 2 44

352

46.

: 9 .

. . 20 1

3 i

;.;:::

:;:: : 9'41

.:::::

::: :r;::

a;?i

tt:::~

:~:::

:%H

i~%

::/::Q

: ::t:

~ili:

aig

i~::t

Pt~:

:::~~

~:t%

m~~

:~~~

:l0!i

T~J

~~~:

~Q~~

~~~:

$?til

i~fi

t\?Q

~fi:~

~;.

~~~i

t~N

~i~~

~r~~

~~1f

J~~~

1?:%

1&1W

fJ:$

;;1'M

;~:0

J~;i:

g;~:

tp:/.

:mm

;~f~

(~~~

ili~~

1Gili

~t~.

.:~: :

:~:~

k~?i

~4~

j!~~

~~

4~~

~r~

~1~

~1m

~A

~'?

$j~

~t:Z

~1~

~;~

;:1 i

10 2

014

946.3 802

7 .0 8,02

7 8.5 401

5 50

2 21

5 4,

732

5.0 12

759

16, 5

46 . 2

,688

6.4

74 6

.8 32

549

34.4 45

308

47.

11 ~.

o 15

..

. .;:::

:;. . ::94 7

:.:1.

:;:::

:::::.: :

!::::

7, ~

d?i::

:::::)

: :H

j~ :g

~::~

:L(L

: t X

~ t;

9~l~

iMj:!

~;1;

~;~

:~fi

K~!

~ ~l

~~:m

~~f%

~J~~

l~r~

:b1J

il~~~

if$f

.#t~

~~~\

~J~.

~~~

~~

M~

~~

m::$

t1itB

~~

JM:?

;~~

M0~

m; t

~~

~~

Hl~

11?i

f ~~::

::: : :if

~~~~

~:tA

~~t~

~~~~

l~#.

~::

: ~iI~

~~?t

~m~~

~r~~

::j~~

tif0~

~~:~

~~~Q

~:

:~~g

t~~.

~;~:

:

12 2

016

949.0 760

2 0

7,60

2 8.0 426

0 45

1 228 4

940

5.2 12

542

17,754 2852 8

.064

8. 5 34

522

36.4 47

063

49.

. i 3

. 20

17' '

::'.9

48; i

j.

:'\:::

\:::i;

~~~:

:;:~:

m:::

j:WH

WW

Q~t

m::7

~~~~

::~tf

JHt;~

:m~!

~t~~

~4;~

~~W

~~~0

i:~Q

:j~~~

~~~1

?ijJ

~~if

~1:?

~~_~

;91~

jiiii'

t~~~

f.~f

:if?i

~jg~

~mn;

~1:~

;Mj~

~~'~

?;:~

~;M

; .::

ft~~

~i~?

J~J&

~~~$

~Ji1

~;~:

: :m

m*t

~1;~

!~~m

I~~~

~~~~

:~f~

~~~~

~!~~

~~:~

:f.~

J~1~

~;;~

:;:14 2018 947.1

7,16

6 .0 7

166

7.6 451

9 .0

4.0

1 242 5

163

. 5.5 12

328 19058 3

025

. 9,75

5 1.

0.3 3624.0 38.

. 48,56

9 51

.1

5 . 2019:: .. . :.

:;':94

9 J.

:: .::

': ?:=

:::6. ;

~~~

:::U

Dn:

m~~

~~:!

::Q::~

t~m

:~;~

. ~?1

:%~i

li:%

~~~z

~~:~

1~JE

4;~~

$:i~

rtl~

ffi~

:Q.;~

~i~r

i~7.

~~~J

rPJI

g4~1

iti~;

:?~jjt~ji?~i~~~;;,r~~Jg~gl~t;w.lli~:?'Q~?i~~1i~;~rtt~.~~ . :f

Mj1

'~l:~

fi~J

~a1)

f: :~

:;m~~

i!l~

iii~~

~:~~

m~'

f.~~

~;Q

~~M

~~i~

lf:i

616

202

0 95

4.0

6,7.

07 0 6

707

7.0 479

5 35

1 25

7 5,

4.03

5.7 12

110

. 21587 32.09 12

687

13.

37,4

88 3

9.3 49,

598

52.

17 2021:.

: ::. ::

949:

4.

. ::::

:.: :')::.

.~~5

~(t;:

:ii:~

:mi:~

M~m

::J;f

?m~:

:~:~

~~gg

1:f:

:~lli

.jil(

~~:~

~~:~

~l~~

~;~~

ijj~~

t4r~

~~~q

:ri~

~k~g

~~~t

~~?~

:~~i

~!~f

$!~~

~ftI

tiJ1;

l~f~

~~~Y

:t~;Q

Mli&

i.i?t

~~~n

~ tI~

1~~~

9Ml:

. :j~

~1~

i:g~

~~

t(:~

~~

1ii:~

:~~:

' 'i~

fB~~

~~~~

Mft

~lt4

Ktj)

r&~~

"Rl:

$1;(

)fij:

:l~~~

~.~:

t;,18

2.022 946.7

6,35

8 0 6

358

6.7

5,08

7 301 272

. 566

0 -

6.0 12

.018 2126

1 3,405 12

647

13.4 40,98

9 43

.. 5

300

7 56

.1

9 2023 . .. . . . . 9

51::

B . . .:

.:::

:: i:: ~

~ Q

62~:

:i ~;

~::i~

f,:~

::?%

: ;0' t:

:~/:

~ ;(

j~g:

:m~t

:~~~

t6 ~41~m'~~~ ?~~it~\~~*P;~~~0.~~M~~1J~~, ~

J:r~

JpJ,

~W

I~~

~pl

JI~

~ill

~: l

~ ~~ijJ!fl?J~ f~~1~Wii)M~;~91:

fii:

:~:;~

lj.$;

~ J

~ifi

li~r:

~a~

;~::

:~t~

~Q

;g'q

l~~m

~~~:

;g~1

~~~

~r~~

~Q~~

~~1~

,$4)

t~2.0 2024 954.7 58p

9 0 5

869

6.1 539

6 25

1 28

9 5,

936

6.2 11,

805

24, 9

67 3

, 612

16,

775

17.6 41

552

43.5

. 53,;357 55.

Yea

r

Net

Pre

sent

Val

ue 8

2,97

6Nominallevelized Cost ($/MWh)

Reallevelized Cost ($

/MW

h)

976

37,0

83. 5

341

987

44,4

1012

738

612

2,77

782

220

,213

307

192

434

578

2.4

35.

28.

50.

40.

trj

~ ~ ::r

(D ...

,.

N ~

0 -

02 A

uror

a R

esul

ts (

IRP

IHR

afte

r 08

).xl

s09

~15-

2004

JR

F

AV

IST

1RA

FT

500/0 of C

oyot

e S

prin

gs 2

(C

CC

T a

nd D

uct B

urne

r)~

cono

mic

Ana

lysi

s D

etai

l

Ass

umpt

ions

Inst

alle

d C

ost

140

2004 $Ooos

Fix

ed C

harg

e0 2004$ per kW

-mo

Insu

ranc

e C

ost

213.42 2004 $0005

Inst

alle

d C

ost

500

2004

$/k

WA

xed

O&

M75 2004$ per kW

-mo

Gas

Tra

nspo

rt00 2004

$/dt

h/da

yP

roje

ct C

apac

ity14

2.E

scal

atio

n R

ales

General Inflation

0 percent

Hea

l Ral

e44

4B

tulk

Wh

Fix

ed O

&M

0 percent

Opt

ion

Val

ue000 2004 $ooos

Gas

Usa

ge R

ate

25.

OOOs dthlday

Tra

nspo

rtat

ion

0 percent

Nom

inal

Dis

coun

t. R

eal D

isco

unt

2 percent

5 percent

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Axe

d O

pera

ting O

ptio

n N

et Tota

l Pro

ject

Ene

rQV

Pro

iect

Axed Chr

Total Costs

Fixe

d G

tran

s Pr

Tax

Insu

r.Total Costs

Cos

ts M

arQ

in V

alue

Pro

t Ben

efit

Tot

al V

aria

blC

osts

C

osts

(GW

h) (

$000

5) (

$000

s) ($

0005

) ($

lMW

h) (

$000

s) (

$000

s) (

$000

s) (

$000

s) (

$000

s) (

$lM

Wh)

($00

09)

($00

0s)

($00

0s)

($00

0s)

($lM

Wh)

($0

00s)

($l

MW

h) (

$000

9) ($

lMW

h)1 2005.

. 7.1

4: 2

.: '

:::

,:13;

~!$:

;:::::'

:::::.

::.:::

: :::S:

:::::Q

::::,i

::::j

.~7

~1:;:

::);::

::1 B

;:i::r

B.m

K:~

;Ql~

:~:i~

~m~:

!;::~

9:;t'

~t;it

~~~t

g~~M

~~~9

ji~~~

:;g~Z

i~~;

~j~~

~~~(

Qttf

.~lW

)t;~

4?J~

r~if

i:i$'

;1:~

. ~:::

:::nI

~(~~

~9~p

:r. .

:;!: :n

o;:

1i:;i

::)::~

:::(1

:4)6

) . i

~~J:

~\:?

~:7

ij~~:

m;ji

frti~

Upi

~::;~

Jm~N

i#~~

4Q$:

:;i::!

:fi*

%j:6

~:Jj

:.2 2006 723.5 1293

6 0 12,93

6 17

. 9 317

0 0 936

226 4

332

6.0 17

268

6,36

5 2,

122

(878

1) (

12. 1) 27

606

38.2 44

875

62.

3 2007.

.:.: :

.:: $8

9: 3

' :::. :::

::::J

2~~

i.t::

::::,:

:: :j::

:::;::

;::,::

r.

t():

:U~:

::j 2

;jJj. t

tt':\:

;1 ~

: ?::~

;~~n

t~~~

~~:::

ttl~f

~~jN

~t::i

~Hl~

;~Q

~i!f

),m

t?~'

am~m

?~1~

iM:f

;~~~

~I~~

41~~

lJtJ

~'1~

;~t~

)~~

~M

4~1?

?Tili

~~

t~t:?

; 1:~

$";:

. .

::m(j

.p~. Q

1.Q

f:S1:

;m:jn

;~: $

) :M

L~7

~~t?

i;~:~

m~~

ti~ti;

4:;~

*t~n

!m:#

; 7~

&l:~

~j.w

:~~:

Q::

6 2010 880.

11,4

17 0

11

417

13. 0

3,5

68

802

255

4,62

5 5.3 16

042

11, 699 2

388

(195

5) (

2.2) 29

885

33. 9 45

926

52.

7 .20

11

:, . ::

9. 2!

J;i:.

: :: :

::::::

::1:1

~9~t

;:::::

t:::::

:n::~

t':'

Q::1

:i::::

~~

:1';P

~t::;

:~::H

?1.j .

~9::;

~~~m

:~~~

~~1~

~:m

~;~g

~~1~

;:p:;~

~~:m

~~:tl

:~~~

i1tt1

~:?:

$?~

~w'~

iZq$

l';i~

Jk~~

:11~

~~~:

~;~Q

4;a~

~':~

:4~~

~~~~

*!K

~;M

():

:j:: .

:i~~~

~f~:

:l t~

:~f:

!~ff

ijfi(

);:t'

:;~:~

t::~p

;~~~

il~i;~

~~~;

~~~#

ri0/

4$~t

~~. ::

~~m

~~~~

Q;3

:::8 2012 944.7 10,75

9 0 10

759

11. 4 378

5 73

6 270 4

791

5.1 15

550 14971 2

534

1,95

5 2.

1 31,32

4 33

. 2 46,

873

49.

9: 2

013.

.94

1:.4

: .

. ,

~:::

:1: j

);4~

e::.

;:::::

::::::

:;t:::

::::::

::::.

O:::

:::::i:

j. p;4~

~:~!

::::~

:::'::

:::j:

1. ;T:J

:Nili

~:~~

~:m

:j~~j

j~~~

::~m

i:iH

:t~~~

q~~&

i~:?

7ij:~

~fi~

.~i~

!Jili

~~

m1l

li~~

~~

_Ja:

~~

~~

t1~

~1J

~;J

$~

:?*m

:\~:~

:6j.q;

::~

:~:1

~:~?

A?~

:~m

ti~~m

t~;

~:: :

mr~

?~~4

~:t~

iiliW

m~4

;Wti~

~~d4

t;~~

i::~m

~mi~

~~$(

j/i:;

10 2

014

946.3 1011

9 0 10,11

9 10

. 7 401

5 66

9 287 4

971

5.3 15,

090

16, 546 2

688

4,14

3 4.4 32

549

34.4 47,

639

50.

11 2

015

.,94

7.1

':. :::

. ::::

::::: :9.

~q~~

~:,::

:::::

::::: :r;:!

:::~:

):Q:: )

::m~r

~,$O

$:t!~

tI:1

0; 4

;::nm

ri~:~

h:t~

~~

~*~

~~

*~m

:9:~

~~

i~i!j

~(~

~~

~~

K~

~?~

:~w

.~~~

m~:

t:r!~

!~~~

~~~~

.if~J

~:4~

~??i

~r~~

lj:!~

M1:

;:mtf

u1;:g

~7M

::~1.

::;~~

ili:$;' ?~

~:0

~W

EM

:~;~

~ :~

J~1:

~~

;?~

~nl

$!m

~~

~:;J

~1i

~t:~

M~

~1A

~:~

1~$~

ili~

Q::8

:'12 2016 949.0

9,51

7 0 9

517

10.0 426

0 602 304

' 5,1

66 5

.. 1468

3 17

,754 2

852

5,92

2 6.2 3452

2 36.4 49

205

51.

.13 . 2017 ::, 9

48.0

:.

' :.::

:: :~;1

~~i

.

:::::::

:m;:~

/:::;:

:m:L

p.t~J:

:~;j~

~:m

tf~a

'~:7

XW

%:1

~~~~

~j~~

i~f~

ili:Q

:lli~

Jii!

\i~:~

&iI

m~1

~~I~

J!i.I

~~1g

7Q?l

fj~i

~~I~

~&1.

1g~:

4~~~

:~!t

:~~1

~;9j

~~;~

~~~i

l:m.

:'m~~

j1i~

?t~;

~~~~

:m~%

?;iJ

. ' ~:~:

M~~

~gm

~*i~

~~;:~

~:;~

:mtt~

JmJ#

~i~9

i~r~

~i~1

~?~1

?14 2018 947.1

8,90

3 0 8

903

9.4

.51

9 53

5 32

3 5,

377

5.7 14

281

19,0

58 3

, 025 7

803

8.2 36

240

38. 3 50,

521

53.

15 . 20

19949 :1

: .

. .

:::::8

' $a~

:::,i::

;1:;:

':::

::::::

:::Q

::i:::

n~:~

;~8g

:::::;

::':::

mW

~(~~

Mt:4

:;$~$

ff:~

~1~~

,1!~

;m:!

~;~t

::~iM

~~~Q

?1~!

jf;f

~a~~

i~~1

$~~~

~~1~

1~i:$

~~~l

firi

if!J

4~Q

ti::r

tJt~

p;?t

~m~~

Th~

~l: 1

:~'m

; Tt~

i~~

g;~

,?3.:;

mm

t~r?

9~~i

' ::~

~ir:

~~~j

i~~R

~j~~

~~~'

;~j:p

~~1$

Q~~

tj~:im

~ljll

i*:~

;.~~:

16 2

020

954.0

8,26

8 0

8,26

8 8.7 479

5 46

8 342 5

605

5.9 13,

873

21, 5

87 3

, 209 10

923

11.5 37

488

39.

. 51

361

53.

17 2

021,

.. ::.:

::.:;. 94

9.:4

::: :.: :

;::;:

::l~

~~

2)' :

:\i:::

:::~

::i~:

t::'J

):i::

~i:it

i::1~

~~. ~\

i:::i:

:~iW

:;;~: ::;

(Mr1

fii;~

~~1(

i?1(

i~:tf

jmtQ

m~t

fml.~

~t~1

ri~~

:~~~

~~~!

?~iJ

t1l.~

~q~J

i*J~

~tl~

;i~~f

?1:;'

~alit:~i;~~~~~mf:t~~t~)l~~ffiJ~1~l*f1~X~~ :~~t%:~.

;#~~

f~~!

~~, t~

9:E

~ilii

&.~

gj~~

t;:r1

F:.w

1f,$

$;~.

18 2

022

946.7

7,74

2 0 7

742

8.2 508

7 40

1 36

3 5,

851

6.2 13,

593

21,2

61 3

, 405 11

073

11.7 40

89 4

3.3 54

582

57.

.19

2023

.

' . ;:9!;j

1.:8

::

~:::;

\:::: 1;~$1 ::~~:;'::Ni:'~;;:~~1;~~J)

?Y:'

::::1

~ ~~

!' :~

~j~:

im~m

:7W

. J:n~

rm~;

~;g

~~i'~

r:fi

WJ\

Q:f

~~f1

~~~:

.~~

111!

f~z~

~'k1

t~~~

~~~-

~~t~

.f&

~~t~

;~

~~

~~

~:?

A;1

' ~~~

~*~l

~~

$Qti

. ~rc

t:4;~

~ )~

~1FU

JJ $

~ l fft:M ;ggZI~tfm4?~

?l~~

~:~

~ i~

4. ~

:ill~

~~l~

~~~.

20 2024 954.7 707

5 0 7

075

7.4

5,39

6 33

4 385 6

116

6.4 13,192 24

967

3,61

2 15

, 388

16.1 41

552

43.5 54

743

57.

Yea

r

Net

Pre

sent

Val

ue 1

05, 1

38N

omin

al L

evel

ized

Cos

t ($/

MW

h)R

eal L

evel

ized

Cos

t ($/

MW

h)

0 105,

138

37,0

83. 7,

121

649

853

151,

991

122,

777

822

392)

307

192

459,

183

12.

(0.

(0.

35.

28.

53.4

43.

'"C

tr1

~ ~

(JQ =-

0'"

J-oI

. - .

~f'"

'I"Q

~

....,

02 A

uror

a R

esul

ts (

IRP

IHR

afte

r 08

).xl

s0~

-15-

2004

JR

F

AV

I5T

.':5

lRA

FT

500/0 of C

oyot

e Sp

ring

s 2 .

(C

CC

T a

nd Duct Burner)

Eco

nom

ic A

naly

sis

Det

ail

0 percent

0 percent

Ass

umpt

ions

Insu

ranc

e C

ost

Gas

Tra

nspo

rtG

ener

al In

flatio

nO

ptio

n V

alue

320.13 2004 $ooos

00 2004

$/dt

hlda

y0 percent

000 2004 $ooos

Nom

inal

Dis

coun

tR

eal D

isco

unt

2 percent

5 percent

Inst

alle

d C

ost

Inst

alle

d C

ost

Proj

ect C

apac

ityH

eat R

ate

Gas

Usa

ge R

ate

106,710 2004 $OOOs

750 2004 $/kW

142.3 MW

444 BtulkWh

25.4 ooos

dthl

day

Fix

ed C

harg

eA

xed

O&

ME

scal

atio

n R

ates

Fix

ed O

&M

Tra

nspo

rtat

ion

0 2004$ per kW

-m

o75 2004$ per kW

-mo

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Fix

ed O

pera

ting O

ptio

n N

et Tota

l Pro

ject

Ene

rav

Proi

ect

Fixe

d C

hrTotal Costs

Fixe

d G

tran

s Pr

Tax

Insu

r.Total Costs

Cos

ts M

arci

n V

alue

Pro

ect B

enefit Total Variable os

ts

(GW

h) (

$000

5) (

$000

5) ($

0005

) ($

lMW

h) (

$000

5) (

$000

5) (

$000

5) (

$000

5) (

$000

5) ($

lMW

h) ($

0005

) ($

0005

) ($

0005

) ($

0005

) ($

lMW

h) (

$000

5) (

$lM

Wh)

($0

005)

($lM

Wh)

1 . 2

005.

.. .

::,

::11

4:1,

:: ,::

, ) 9

~3.

()Q

::: ::

::::::

::':::

:;~::t

t~: 9::t)

j:9;~

Q(j

f;::~

:(::;

::it~

(f::t

M~:

j:~;Q

t~:r

~mm

~~~:

~~:~

j:gm

~t:~

~1:r

4Mff

im.%

Il~j

~~q:

;hhl

ffi0

i~~~

~g:r

~If~

1~~~

~Q_1

W1~

4~j.

1~~t

t:~~1

~t:~

~;;)

:?~9

~P:::

:: J:

(f6;

~ $

om~

;~i.:

(?~

~z)

:':nr

2~;1

.~~

)f~

wJA

Q:~

~ll~

~~

:~:::

$~;~

g$i~

!~1J

ii:4j

::,2 2006 723.5 1866

7 0 18,66

7 25

. 8 3

,170

. 0 1.404 340

. 4.91

4 6.8 23

581

6.365 2

122

(15,

093)

(20

.9) 27

606

38.2 51

187

70.

3 . 2

007,

.. .

()89

: 3.. ,

: .. :::

.:1 B

;~~

O: :

:::

::~::::

,:::' !::t:

.:i:::

::t)

'::,;:

:l:j. ~

~9j

Q;::

::::::

'/::::

:~6.

~::~

~nm

:~;~

~~

;~)~

i::tll

it~nf

:.Q::~

\!~m

ti~M

l!~?

i~lM

~~m

~8~~

:~;~

, ~~!

:r~~

Jit~

~t~?

~t~1

Itt.:

l;~;~

~ij:l

lm~t

~~;1

~~~f

~~~i

llp:?

;i ~.

~:~;

:. . :::

aj.~~

q~j.

::;W

%:~

?ij:~

j ::WC?!;~!tJ~~~WA(ji4:~t~~1~r(~i):~7 ~:jtj~~i~fj'

t~:.i

j.

6 20

10 8

80:9

.32

4. . "

..., .

0 ..

324

. """

18.5

.", .

3;56

8'. .

.' ...

" 0

."204' .", .. 3B

~i..

. '5

;.154

..."

' 5:9

.

.,., .

.'."

21;4

7Ef'

'11

~699

."""

'.2;

388.

. ."'

(i;3

9'i)

.-. .

.(8

:4)

. . "

29;8

85' .

".'3

3'.9

.' ."

'..' 5

(362

."".

.. i;8

.7 . .2

0 11

.. ~

2Q; .7

:::::::

:.: ~::1

~;~

1'7

'

:' :::::\

::::::

:):i:

::~:::

::O'

:r;::

;);$

;~

tt::m

:m;:u

~7;~

::::j:

~~m

~:~'

;~1$

:~r~

~f~~

mf1

(ej~

~~t:f

j.;:r

$~W

:1~~

:~~4

~1~~

ThR

mr$

;g~~

;~~i

1ili~

~~'j

~~t~

1~gt

'p~~

:~~~

NJj

~;4~

~~m

m:g

~M9;

:;. :

ffi!

~~::(

$~

ij :~

F~

m~

mm

:(5:

;$)

':M;1

~9:

~~

~~

~iiW

~1J

r~~

:;~;~

!M~

~t~

::$~

:'~

t~r~

~~;~

~~~:

;~'

8 2012 944.7 15.29

8 0 15,29

8 16

. 2 378

5 0

1,10

3 40

6 5,

294

5.6 20

591 14971 2

534

(308

7) (

3.3) 31,32

4 33

.2 51,

915

55.

9 20

13 .

: .::9

41':

4 ::

.:::': ::

: 14; t

n9:

::::'.

:::::i

:;::

;:~: L ?

::::: :

6::: 2

\ ~4

~:~

1,m

::

;:%:: 15

/7:

:%W

J:~e

~;~

~M~~

~i$j

1mjtQ

!~~!

T:tX

:~ ;;

Q$~

~11w

1~~J

IDti'~jpJ~~~41Q~~f~/l jllii,~~W;~'?P

: f~~

mik

~tiJ

~; 1

~$! ~

fJl~

m(~

~;~~

J1.

: ~~:. ,r

,m::(

~~~?

4)

:~~~

f;&

~~:(

~: ij

) :~

:~i::

~? iM~ :)W-J~1~~i~1;

4~;$

~ft~

r~

i;

$~~ ~ im

~~~~

1:::~

:5X

~

12 2

016

949.0 13,34

7 0 13

347

14.1 426

0 90

3 45

6 5,

619

5.9 18

966 17754 2852 1

639

1.7 34

522

36.4 53.48

8 56

.413 '2017

. .:.

.

4~.O

.:::::

':1

:?, M

?:: ::

:::I:

~t~t

' mt:i

j:~:m

:G1?

i~4?

)~W

6Ij ~

~~

kt~

~lj:

(4.~

~~

B.;~

~;~

~fr

~m

\:91j

~~

j!t~

~1~

&~

i~1r

if~ili

, 47j1:~mW~;zj;9.i~1f:~(Q!t\*1t1fit~~~~g:t~i!f~~~R)!Z;;~t~~~~~zU, gmt:~~lij~a~$i~m~~~'

: '

~~m

:~~~

~~gi

~*~1

~~~~

~~~f

1~1\

~'~~

~~~4

f1~t

i(~~

r~t:

14 2

018

947.

1 .

379

0 12.37

9 13

.1 451

9 80

2 484 5

806

6.1 18

185

19, 058 3

025

3,89

8 4.

1 36.24

0 38

. 3 54

426

57.

1 5

. :20

19

' . .

. ,. "

: . 949 ::1.,

. ::::

:: :' :~

;::

J t;

~ ~

Q. :

;:j: :::

::: :i~

g~~

~f \

p:: :

::j&

j: t;

~. ~

i:tr~

:i?W

:: j .

g ~

~:m

t~11

~:~

; $~$m

~~k1

4iiig

l~l~

~~r?

$g

~ti1

~~

~~

~j'i

Th1

~~

i ij Q

ijl~~J:~:~ ~?J~!!~.~j1i it ~ ~~

w.r

J::?

Qi

?iA

i~~~

l~~

1: t

ij :;~

: .m

~~(~

;~Q

~H~

1~IM

~~~:

~~~:

' : 1?

~J~~

iEtf

f~~t

~f~t

r~ij:

;Q:j:

~~1~

1~~

~$~,

~ : ;~

t~~~

~!:

i~:'

16 2

020

954.0 1139

0 0 11

390

11.9 4795 0

702

514 6

010

6.3 17.

400

21, 5

87. 3209 7

396

7.8 37

488

. 39.3 54

B88

57.

. . 17 2021

:::::.

",.:: . :

9 49

. -4'

. ::::::

:; :::, it

0;9

~ $

:';f:t

tl~:

~m~!

:~:~

:.Q

:':m

~ ~ :

i) i~

~~

:::&

f1a

:t 1;

; ~:~

i~f~

~ ff

i'4i~

~~f&

1W~~

~P1m

1jf!

~::~

~!~g

rJ1~

~~~:

rii~

l~:ii

~90B

~1~~

~~:~

ifJ1

It~q

~~J~

~?J

~~ ~

j~;~~~ ~ ~~~~~I.~~~fIl;~M1Jt~mf~&~,

~tH

?:j :

;~~~

~~.~

~~~:

~:~1

1~!

~J:~

Q1~

~~ri

:~~~

jJg$

;lff

i!~~

ffi ~

~r

Q :

1B 2

022

946.7 1050

9 0 10.50

9 11

. 1 5

,D87

60

2 54

5 6,

233

6.. 16.

743

21. 2

61 3

,405

. 792

3 8.

4 40.98

9 43

.. 57

732

61.

1 9

2023

"'::

::"'.

95 fa:

::::::

:'::)' , 9

: 9 4f

J:?:

::

:,: ~:

~::1

i:~

~:~~

~:~/

O::i

~::~

:;~:;

'9

'4t

'H::

:~:~

:~~

8:

1. 0

:. 5:

~)~*

,i~5:

~39~

t1'~

~~

~~

~~

: o:tf

.i~t:w

f'2,

~~1-

t!5G

j!t.~

""ii(

l6

2r~~

~f~; .

(3:7

1f.~

l,t~1

.)30

0~1~~

1 24 ' :

163:

~~

8~~

';3 :

sot

::t~H

fr37

:():

i~~~

~(%

?~~p

: :Jl :

;~~~

~4d;

i~

~~~i

r4 i

:~t ~

~~~~

I1lli

56:5

0a :~

~~~~

t;ii!

f4:

. ..'

. ...

....

...".

..

'v.

....

"'.

'...

"""~

.'.""

"~'""

'".

:'.

"""'

."'i.

""""

""."

",.;.

-.."

..".

..-,

,... ,'i

i'.~"

,~,(

".

""""

","~

"."

..-,

-".

,,,.,'

...,"

""""

",,..

"'. "

.",..

:..,.

".,..

"""

....

.-".

,.....

...

~w;"

.

.,.."

",.

."."

.".

..."

.

"""v

;'.

20 2024 954.7 9.48

9 9,

489

9.9

5,39

6 50

2 57

8 6,

476

6.8 15,965 24

967

3,612 12

615

13.2 41,55

2 43

. 5 .

517

60.

Yea

r

Net

Pre

sent

Val

ue 1

49,4

63Nominallevelized Cost ($IMWh)


/MW

h)

0 149,

463

083

10,6

8297

373

820

120

012

277

782

2(5

3,60

1 )

307

192

508,

392

17.

14.

(6.

(5.

35.

28.

59.

47.

trj

~ ~

(JQ =-

(D .,

..

"""'"

.,..

... ~

0 ~

02 A

uror

a R

esul

ts (

IRP

IHR

afte

r O

B).

xls

09- 1

5-20

04 J

RF

AV

IST

.. ..

-:' R

AFT

500/0

of

C

oyot

e S

prin

gs 2

(C

CC

T a

nd D

uct B

urne

r)E

cono

mic

Ana

lysi

s D

etai

l

Ass

umpt

ions

Ilns

talle

d C

ost

986

2004 $ooOs

Fix

ed C

harg

e0 2004$ per kW

-mo

Insu

ranc

e C

ost

Inst

alle

d C

ost

478

2004

$/k

WF

ixed

O&

M75 2004$ per kW

-mo

Gas

Tra

nspo

rt

Pro

ject

Cap

acily

142.

Esc

alal

ion

Rat

esG

ener

atln

flat

ion

Hea

t Rat

e44

4B

tulk

Wh

Fix

ed O

&M

0 percent

Opt

ion

Val

ue

Gas Usage Rate

25.

Ooo

s dt

tVda

yT

rans

port

atio

n0 percent

203.96 2004 $Ooos

00 2004

$Idt

tVda

y. 3.0 percent

000 2004 $ooos

Nom

inal

Dis

coun

tR

eal D

isco

unt

2 percent

5 percent

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Fix

ed O

pera

ting O

ptio

n N

et Tota

l Pro

ject

Ene

rov

Project F

ixed

Chr

Total Costs

Axe

d G

tran

s Pr

Tax

Insu

r.Total Costs

Cos

ts M

aroh

l Val

uePr

ot B

enef

it Total Vari

ble

Cos

tC

osts

(GW

h) (

$000

s) (

$000

s) ($

0005

) ($

lMW

h) (

$000

5) (

$000

5) (

$000

s) ($

OO

OS)

($00

0s)

($lM

Wh)

($00

05)

($00

05)

($00

05)

($00

05)

($lM

Wh)

($0

005)

($l

MW

h) (

$000

s) ($

lMW

h)

2 2006 744.3 1246

3 0 12

463

16.7

3,1

70 0 895

. 216

. 4

281

. 16

744

6,395 2

122

(8,2

27)

(11.1) 28

342

38.1 45

086

60.

8 2012 944.7 1035

6 0 1035

6 11

.0 3

,785

70

3 258 4

746

5.0 15

103 14971 2534 2

402

2.5 31

324

33.

46,4

26 4

9.

10

2014

94

6.3 9.74

8 0 9

748

10.3 401

5 63

9 274 4

929

5.2 14

677 16546 2688 4

557

4.8 32,54

9 34

.4 47,

225

49.

12 2

016

949.0 917

7 0

9,17

7 9.7 426

0 57

5 29

1 5,

126

5.4 14

303 17

754

2,852 6

302

6.6 34,52

2 36

.4 48,

825

51.

14 2

018

947.

1 8,

595

0 8,

595

9.1 451

9 51

1 30

9 5,

339

5.6 13,

934

.058 3

025

8,14

9 8.

6 36,24

0 38

.3 50

175

53.

16 2

020

954.0

7,99

1 0 7

991

8.4 479

5 44

7 327 5

569

5.8 13,561 21

587

3,209 11

236

11.

488

39.3 51

048

53.

1B 2

022

946.

7,49

6 0

7,49

6 7.

9 5,

OB

7 38

3 347 5

817

6.1 13,

314

21,2

61 3,

405 11

352

1~.0 40,98

9 43

.3 54

303

57.

20

2024

954

.7 6

.861

6~

861

7.2

5,39

6 32

0 36

8 6,

084

6.4 12

946 24

967

3,612 15

634

16.4 41

552

43.5 54

497

57.

Yea

r

Net

Pre

sent

Val

ue 1

01,2

76N

omin

al L

evel

ized

Cos

t ($I

MW

h)R

eal L

evel

ized

Cos

t ($I

MW

h)

0 101,

276

083

805

531

46,4

2014

769

612

287

482

2(0

)30

8,63

045

632

6

11.

(0.

fO.

35.

29.

53.

42.

""d

~ ~

IJQ =-

S"-

UI

"""

0 ~

02 A

uror

a R

esul

ts (

IRP

IHR

afte

r 08

).xl

s

IN""

'"'

RA

FfA

VIS

T"

500/

0 of

Coy

ote

Spr

ings

2 (

CC

CT

and

Duc

t Bur

ner)

Eco

nom

ic A

naly

sis

Det

ail

Ass

umct

lons

Iins

talle

d C

ost

966

2004

$oo

osF

ixed

Cha

rge

0 2004$ per kW

-mo

Insu

ranc

e C

ost

203.90 2004 $ooOs

Inst

alle

d C

ost

478

2004

$Ik

WF

ixed

O&

M75 2004$ per kW

-mo

Gas

Tra

nspo

rt00 2004

$Idt

hlda

y

Pro

ject

Cap

acity

142.

Esc

alat

ion

Rat

esG

ener

alln

flaU

on0 percent

Hea

t Rat

e44

4B

tulk

Wh

Axe

d O

&M

0 percent

. Opt

ion

Val

ue000 2004 $0008

Gas

Usa

ge R

ate

25.

ooos

dth

lday

Tra

nspo

rtat

ion

0 percent

Nom

inal

Dis

coun

tR

eal D

isco

unt

2 percent

5 percent

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

c~ T

otal

Fix

ed O

pera

ting O

ptio

n N

et Tota

l Project

Yea

r E

nerQ

V P

roie

ctF

ixed

Chr

Tot

al

osts

Fi

xed

Gtr

ans

PrT

ax In

sur.

Total Costs

Cos

ts M

arQ

ln V

alue

Pro

ect B

enef

it T

otal

Var

iabl

e C

ost

Cos

ts

(GW

h) (

$000

5) ($

0005

) . (

$000

5) (

$lM

Wh)

($0

00s)

($0

005)

($0

005)

($0

005)

($0

005)

($lM

Wh)

($0

005)

.($0

005)

($0

005)

($00

05)

($lM

Wh)

($0

005)

($l

MW

h) (

$000

5) ($

lMW

h)

4 2008 690.8 11,64

6 0 11

646

16.9

3,3

63

830 229

. 442

3 . 6.4 16069 4

450

2,25

1 (9

,368

) (1

3.6) 28,

229

40.

298

64,

; .~~

!,::~

' !i,i:

i&~I

:::;!

:~~;

m~:

~r=

;;:~:

.r:lr~

I;~:l

l=tC

II=

I~=

~= :1

r.1=

11::1

~~:1

;!:

B 2

012

944.7 1035

4 0 10,35

4 11

.' 3785 O

703 258' 474

6 5.0 15,

100

14,971 2

534

2,40

4 2.5 31

324

33.

46,4

23 4

9.

10 2014 946.3 974

6 0

9,74

6 10

.3 401

5 0 639

274 4

928

5.. 14

674

16,5

46. 2688 4

559

.8 32

549

34.4 47

223

49.

12 2016 949.0

9,17

5 0 9

175

9.7 426

0 57

5 291 5

126

5.4 14

301

17,754 2

852

6,30

4 6.6 34

522

36.4 48,

823

51.

14 2

018

947.1 859

3 0 8

593

9.1

4,51

9 . 0

511

308

533

9 5.

. 13,932 19

058

3,02

5 8,

151

8.6 36,24

0 38

.50

,173

53.

':'::;

::15

::' ; f

!9 1

.~: ;

~;Jk

tM 9

~~,~

m:m

f1J~

:~'~?

~~~ ~~~~~~1fjS:~t\~;J~~!~ 1?~?:~ii.i~1tr~E&Jr:. ::DI~Q~?tQ~qj~~~;tl~'

:ir:ii,~~~~~~~.1?li9I?t ~Jre~~~~~tz ij~i~~:~1~iIiIl~Qi~

1~~w

.~~~

~J;?

~

16 2020 954.0

7,99

0 0 7

990

8.4

4,79

5 44

7 32

7 5,

569

5.8 13

559 21

587

3,20

9 11

,238

11.8 37,48

8 39

.3 51,

046

53.

... ,.

. ...

,.,.

...,"

~....

.. '.

"..'.

h','"

. ,..

..,

t:i'."

""

"'""

"~",

.""

,,,,

,".,.

,

V.'.

""~"

'.N

;;:.

".h"

'.!'!!

'.""

'..""

' !ff'.

'~"""

""".

'"'

*"".

."~'

...

"w,~

.;!'J

~.

""""

"'"'

.""""

"".'~

""""

"!!'!

~' ,\i""

.

~"""

-"~;

".

;!'r'

.~W

:'.

"'.

i(."

""'Z

i!f';

..,."

;.

,,;~

.,,,.

. w_"

'~."'

.

:r:~

..

.'..=. " i~

;;;'~.

'-""

""

~~fi

.l"""

.""~K

~.""

".".

'I;/!

#,""

.&'."

. ..

.~...

..

18 2

022

946.7 749

5 0 7

495

' 7. 9

5,087 O

' 383

347

5,8

17. 6.1 13,312 21261 3

405

11,3

54 1

2.98

9 43

.3 54,

301

57.

20 2

024

954.7 6B

60 0

686

0 7.2 539

6 31

9 36

8 6,

084

6.4 12,944 24967 3

612

15,6

36 1

6.4 41,55

2 43

.5 54

496

57.

Net

Pre

sent

Val

ue 1

0118

2N

omin

al L

evel

ized

Cos

t ($I

MW

h)R

eal L

evel

ized

Cos

t ($/

MW

h)

0 101

182

083

. 6,

803

531

46,4

1714

7,59

912

2,77

782

2(0

)30

719

245

479

1

11.

(0.

35.

28.

52.

42.

trj

~ ~

(JQ =-

('D ..

. .....

0"1 f""I'o

Q ~

...,

02 A

uror

a R

esul

ts (

IRP

IHR

afte

r 08

).xl

s

AV

IST

, :R

AFT

500/

0 of

Coy

ote

.Spr

ings

2 (

CC

CT

and

Duc

t Bur

ner)

Eco

nom

ic A

naly

sis

Det

ail

Ass

umct

ions

Iins

talle

d C

ost

455

2004 $ooOs

Fix

ed C

harg

e0 2004$ per kW

-mo

Insu

ranc

e C

ost

211.36 2004 $ooos

Inst

alle

d C

ost

495

2004

$lk

WF

ixed

O&

M75 2004$ per kW

-mo

Gas

Tra

nspo

rt00 2004

$Idt

hlda

y

Pro

ject

Cap

acity

142.

Esc

alat

ion

Rat

esGeneral Inflation

0 percent

Hea

t Rat

e44

4B

tulk

Wh

Fix

ed O

&M

0 percent

Opt

ion

Val

ue000 2004 $ooos

Gas Usage Rate

25.

ooos

dth

lday

Tra

nspo

rtat

ion

0 percent

Nom

inal

Dis

coun

tR

eal D

isco

unt

2 percent

5 percent

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Fix

ed O

pera

ting O

ptio

n N

et Tota

l Pro

ject

Ene

rQV

Pro

iect

Fix

ed C

hrTotal Costs

Fixe

d G

tran

s Pr

Tax

Insur. T

otal

os

ts

Cos

tsV

alue

Proect Benelit

otal

VC

ost

Cos

ts

(GW

h) (

$000

5) (

$000

s) ($

000s

) ($

lMW

h) (

$000

5) (

$000

5) (

$000

5) (

$000

s) ($

0005

) ($

lMW

h) ($

0005

) ($

0005

) ($

0005

) ($

000s

) ($

lMW

h) (

$000

s) (

$lM

Wh)

($0

005)

($lM

Wh)

6 .

:: "'

:'..

~r .

~ :"'':':'~

.:"

":':'

:.:';'

:':;:'

:.:':':"

':.:'~

. .:..

.. ~

.'

. O:.:

":':'

;.!':"

?:.:'

:''.:.

:':':;

:.:.

'.':' "J

:"";

":~'

:.~'

:':'::

F")'~

'~'

~"""

';;:'1

i'.:(

"'1

,;.(.

;,::~~ A

2'?~

~'1~

~"'r~

~

. .. :

~"1;

.. qi!"

"-"'

;'*i'

?;'%

'.""'

~;'

~~~"

~~~"

~":(

.~, J~

!.

';.(:

~~~

::'

;,n~

~~~~

~i:f

.~:J

~w

.:;:j~ ~~

,Y.t'

~"

:: . .

.

' \::,

::, .

. . ~

; ..:

/'::(

. . i.

. ../~

;~:~

:~~~:

;:;*:

*;',:

.. :::

:::+

~ .

..."

;::;i!

:;~:;~

:\ Y

~::;;

;~:;.

iI~,

:S~.:

~~4f

.~~~

~,,:

i~:;~

~r';t

:\,

. .

~~1~

~;;,:

i\~it:

~~;:~

:;,~~

~h?,

,H~i

;&t1

.r&

i.:~:

'it~:

J~2i

E~~

t"~_

i:~:,

.\:J.

,:;i.~

1~;!

,i.~

.~~~

~I'j*

,-~,

~, .

. ~::::

;i;~

:J,;J

'

" ,:!

$.~~

~,~~~

\:.,;

:.

. ~~\i~tL...

:~.. 'f"

*'~~

"tR

'Sj:!

i\~;;:

,gp,

;;;.:t

",~"

':'~~

hfJ~

"!.

:;,.

4 20

0B 8

62,7 12,00

2 0 12

002

13.9

3,3

63

861

238 4

462

5.16,464 10

697

251

(3,5

16)

(4.1) 27

914

32.4 44,

378

51.

8 2012 891.4 1069

4 0 10

694

12.0

3,7

85

728

268 478

1 5.4 15

476

12,733 253

4 (2

09)

(0.2) 31

802

35.7 47,

277

53.

10 2

014 890.4 1009

3 0 10

093

11.3 401

5 66

2 284 4

962

5.6 15,

055

13,442 2

688

1,07

4 1.

2 33,69

4 37

.8 48,

749

54.

12 2016 891.3 950

4 0 9

504

10.7 426

0 59

6 301 5

157

5.8 14

661 14

339

2,85

2' 2

529

2.8 35,78

8 40

.2 50,

450

56.

. . 14

201

8 .

892.

.. '.'

8;92

1 ..,

......

.,. .

. ...

921

,.

... "

1ojf

519.

.53

0 32

0 5,

369

6.0 14

290

15,146 3

025

3,88

1 4.3 37

996

42.6 52

286

58.

16 2020 893.0 834

5 0

8,34

5 9.3 479

5 464 339

. 5,59

7 6.

. 13,943 16

138

3,20

9 5,

405

6.1 40,

356. 45.

54,2

99 6

0.

18 2

022

891.6 777

2 0 7

772

8.7

5,08

7 39

7 36

0 5,

844

6.6 13,616 17

067

3,40

5 6,

856

7.7 42,73

2 47

.9 56,

348

63.

20 2

024 892.4 721

3 0

7,21

3 8.

1 5,

396

331

382

6,10

9 6.8 13

322

18,1

61 3

,612

8,4

52 9

.5 45,39

0 50

.9 58,

712

65.

Yea

r

Net

Pre

sent

Val

ue 1

0464

8N

omin

al L

evel

ized

Cos

t ($1

MW

h)R

eal L

evel

ized

Cos

t ($/

MW

h)

0 104

648

083

053

623

46, 7

5915

140

712

6,58

582

2(0

)31

479

646

620

3

12.

(0.

(0.

36.

29.

54.

43.

~ ~

fJC

I =

-(t

) _.

J-8

......

,J ..

..

0 ~

....,

03 A

uror

a R

esul

ts (

1050

0 H

R).

xls

AV

IST

If'"

'l". "

flA

FT

500/

0 of

Coy

ote

Spr

ings

2 (

CC

CT

and

Duc

t Bur

ner)

Eco

nom

ic A

naly

sis

Det

ail

!Inst

alle

d C

ost

Inst

alle

d C

ost

Pro

ject

Cap

acity

Heat Rate

Gas

Usa

ge R

ate

0 percent

0 percent

Ass

umpt

ions

Insu

ranc

e C

ost

Gas

Tra

nspo

rtG

ener

al In

flatio

nO

ptio

n V

alue

211.

41 2

004

$ooO

s 00 2004 $/

dth/

day

. 3.0 percent

000 2004 $ooos

Nom

inal

Dis

coun

tReal Discount

2 percent

5 percent

70,471 2004 $ooos

495 2004 $/kW

142.3 MW

444 BtulkWh

25.4 ooos dth/day

Fix

ed C

harg

eF

ixed

O&

ME

scal

atio

n R

ates

Axe

d O

&M

Tra

nspo

rtat

ion

0 2004$ per kW

-mo

75 2004$ per kW

-mo

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Fix

ed O

pera

ting O

ptio

n N

et Tota

l Pro

ject

Ene

rov

Proj

ect

Fix

ed C

hrTotal Costs

Fixe

d G

tran

s Pr

Tax

Insu

r,T

otal

Cos

tC

osts

Mar

cin

Val

uePr

oect Benefit

otal

Var

ble

osts

C

osts

(GW

h) (

$000

s) ($

000s

) . (

$000

s) (

$lM

Wh)

($0

00s)

($0

009)

($0

00s)

($0

005)

($0

00s)

($h

.1W

h) ($

000s

) ($

000s

) ($

0005

) ($

0005

) ($

lMW

h) (

$000

5) (

$lM

Wh)

($0

005)

($lM

Wh)

4 20

08 7

48.1

11,83

7 0 11

837

15.8

3,3

63

861 238

. 4,462. . 6.0 16,

299

10,595 2

251

(3,4

53)

. (4.6) 24,41

8 32

.6 40,

718

54.

B 2

012

891.4 10,69

6 0 10,69

6 12

.0 3

,785

72

9 268 478

1 5.4 15478 12

733

2,53

4 (2

11)

(0.2) 31,80

2 35

.7 47,

280

53.

10 2014 890.4 1009

5 0 10

095

11.

. 401

5 66

2 284 4

962

5.. 1

5057 13

442

.. 268

8 1,

072

1.2 33

694

37.8 48,

752

54.

12 2

016

891.3 950

6 0 9

506

10.7 426

0 59

6 30

1 5,

158

. 5.8 14

663 14339 2852 2

527

2.8 35,78

8 40

.2 50

452

56.

' ~ :;

~; :;

::;m

.i:::i

E:::

a:~:

i;I::1

f~~:

fJC

=1~T

:I:;=

=~r

.:1iC

JIC:!~C~ :rC

C~~

a:I~

;16 2020 893.0 834

7 0

8,34

7 9.3 4795 O

. 464

339 5

598

6.3 13,944 16

138

3,20

9 5,

403

. 6.1 40,35

6 45

.2 54,

300

60.

18 2

022

891.6 777

3 0 7

773

8.7

5,08

739

7 36

0 5,

844

6.. 13,

617

17,0

67 3

,405 6

855

7.7 42,73

2 47

.9 56,

349

63.

.:.. .

....

..,. .

.:..'.

' '.

S,"'

t.1-

'..0

.*".,.

..:;..

",.,,

;.,...

","'

"'."

"'

::r.'/.

"~"

""""

"

.:i'""

'~.';

!"':'

.~:

":",

~,~"

""",

;~""

;,,,,,

..~~,

. t(.

:t~~~

"1i1

7!i"

".~'

i!;'.

,:.p.

l""-

~'

~"""

W"f

',l,"

'":1

'-".:;;"'

:'.I"

"i;'

;'/"'

'. '~

.

""I"

~~

"".

' ". "

""',"

'.

'H "

"""~

~'/

i!" "

'~"!

i'.'?

i;;;"

.""'~

;". _"

fjj~

. '~A

~"~"

"'"u.'"

'dl

""~'

~"'.

"'.

'.'.

19.:;

;202

3;';=

:0:::

';;;:;

.. .. .

::: 5:~:

:i\:~

'J~4

~7/li

!:~:

/i:!~

~(8:

::~:: :

::Q:::

::;:l~

:g~~

~?:~

;:~::~

::~:;~

!:::;;

!HW

~~li~

i:~.;~

~.

:~q:

if~~

J?~~

~:tP

tf~r

~~~~

~,?:

tJ;.~

,W~7

.iPoB

/t!!i

.~~~

-!*~

~j".i:

~~1?

~'%

l~..

~!.)

~~;s

wJt

~%1~

~~I?

,.:'~

;:,~t

;'t7'

.zr,

j~iB

~,P.

. '::~

~: . ;f

~11;

i~1!

q~Pi

~!~1

,.;tJ

~$...;~

:

'~$r

,~i~

i~?~

i.~~.

.?e~

.=!~

~8~~

1:;~

:

:~~. !?

':!:~

~~~~

fr~~

;~;

20 2

024

892.4

7,21

4 0 7

214

8.1

5,396 0

331

382 6

109

6.8 13,

323

18,1

61 3

,612 8

450

9.5 45,39

0 50

.9 58,

713

65.

Yea

r

Net

Pre

sent

Val

ue 1

0400

3N

omin

al L

evel

ized

Cos

t ($/

MW

h)R

eal L

evel

lzed

Cos

t ($/

MW

h)

0 104

003

083

. 7,05

462

446

,761

150

764

125,

942

822

(0)

300,

893

451,

657

12.

10.

(0.

36.

29.

54.

43.

""'d

tfj

~ ~

(JQ =-....

....

CO

f""I

"-

0 -

03 A

uror

a R

esul

ts (

1050

0 H

R).

xls

A VIST'

. '

T!'

'N'

. "'R

AFT

500/

0 of

Coy

ote

Spr

ings

2 (

CC

CT

and

Duc

t Bur

ner)

Eco

nom

ic A

naly

sis

Det

ail

Ass

umpt

ions

IInst

alle

d C

ost

144

2004

$O

oos

Fix

ed C

harg

e0 2004$ per kW

-mo

Insu

ranc

e C

ost

138.43 2004 $ooos

Inst

alle

d C

ost

324

2004

$/k

WF

ixed

O&

M75

200

4$ p

er k

W-m

oG

as T

rans

port

00 2004 $/

dthl

day

Proj

ect C

apac

ity14

2.E

scal

atio

n R

ates

General Inflation

0 percent

Hea

t Rat

e44

4B

tulk

Wh

Axe

d O

&M

0 percent

Opt

ion

Val

ue00

0 .2

004

$ooo

sGas Usage Rate

25.

ooos

dth

lday

Tra

nspo

rtat

ion

0 percent

Nom

inal

Dis

coun

tReal Discount

2 percent

5 percent

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Axe

d O

pera

ting O

ptio

n N

et Tota

l Pro

ject

Ene

rc1V

Pro

ject

Fix

ed C

hrTotal Costs

Axe

d G

tran

s Pr

Tax

Insu

r.Total Costs

Cos

ts M

arai

n V

alue

Proect Benefit

otal

Var

ible Costs

Cos

ts(G

Wh)

($0

00s)

($0

00s)

($00

05)

($iM

Wh)

($0

005)

($0

00s)

($0

00s)

($0

00s)

($0

00s)

($/

MW

h) ($

000s

) ($

000s

) ($

000s

) ($

000s

) ($

iMW

h) (

$000

5) (

$iM

Wh)

($0

005)

($JM

Wh)

. . .' :

:.::. . ' 1

."'2

005.

:::::5

:746

; ~m

: m;M

l;,

~; ?

()~

::

fil~

%~

J~ili

~;~

tJH

m\~

! p ;?

P~

: ~W

2~\'

?4: ~

~~~~

t*~~

ijt~

M~~

~1~~

~iU

t~~i

~*I~

. g~J

Jtw

.W~t

1.~;

.;r:~

.~l~1

9~fi

l~j~

~ii1

ilill~

l~~

9~1.

r~lt~

;Jr~

;M~1

0fri

~~ ?

':;Q

~Q.~

:. t;t

!:t~

~~

I 1 )I1)~~~j~;9) . ~Jilif?a:

~!9~

l;fi~

r~~:

~ 1~

!Ji~

jl~jW

$g:

E~~

ili~~

;~:'

8 2012 777.4 7,57

3 0

,57

3 9.

7 3,

785

477

175 4

437

5.7 12

010

9,133 253

4 (3

44)

(0.4) 31

399

40.4 43

410

55.

10 2

014

781.6 719

5 0 7

195

9.2 401

5 43

4 186 4

635

5.9 11,830 10

210

. 2688 106

8 1.4 32,87

6 42

.1 44

706

57.

12 2016 798.7

6,84

9 0 6

849

B.6 426

0 39

0 197 4

848

6.. 11,69

7 11

,481

2,852 2

635

3.3 35,01

0 43

.8 46,

707

58,

2018

"'..

807.

'6.'

.6;

492

'" .

... .

0..."

..6;

492.

. ,.. '

0 ."

'.51

9. '

n "0"

.. . 3'47' o. ""20

95;

ois.

' 3.

.,. f1'56

8 ...

.2;

739:

".

025.

". '.

'.

1'96 ". .

sji

". ..

36;E

is4"

. 4.

5).. -

.. " 48

;452

Oh.

' 60.

'0

16 2

020

829.8 616

9 . 6

169

7.4 479

5 30

4 222 532

0 6.4 11490 14248 3

209

5,96

7 7.

2 39,

470

. 47.6 50

959

. 61.

4

18 2

022

842.4 583

2 0 5

832

6.9 508

7 0 260

. 236

5,5

83 6

.6 11,

414

15,7

99 3

,405

7, 7

89 9

.2 41,72

1 49

.5 53,

135

63.

. . : . ~: i: :19

::;:

:20 2

:3: l

:: ::;

~ 0: i:

~ $

~ ~.

~ ;::

~1a t~ $~ ~

ij Q

;~f0

~ili W

;;~l1

i: j p

j ~W

t~i ~

i~

~ P:

ll\~ ~

~I~~

; It.~!~i~ i? ~~

:i~.~

~if:

Q_f

ig ~~

~. ~..~ ~jl~~

~lrf

li ~

1~~

~(~

J.~

~.t:

t~1(

1; i.

~; ~

4,~

f.~ f:

ro

~Q i

f;::

r~.i;

ij

JZ~

ff~_i

p.~

~ !;

~:Ii

!~l ~

~~_f

(~Jt

r ~Filr:l(~;~ ?QJ1ttiti~.

~. (

Ji.~

20 2

024

877.3 555

6 0

5,55

6 6.

3 5,

396

217

250

5,86

3 6.7 11

419

17, 5

68 3

,612

9,7

61 1

1.1 45,24

1 51

.6 56,

660

64.

Yea

r

Net

Pre

sent

Val

ue 7

4,20

2N

omin

al L

evel

ized

Cos

t ($/

MW

h)R

eal L

evel

ized

Cos

t ($/

MW

h)

74,2

0237

,083

. 4

619

718

43.4

2011

7,62

280

024

,822

311,

626

429,

248

40.

32.

55.

45.

tr1

~ ~

(JQ

::r

!'\)

....

8"-

\C)

~0

~01

Aur

ora

Res

ults

(in

crea

sing

IHR

).xl

s

. -~

.

QA

FTA

VIS

1

500/

0 of

Coy

ote

Spr

ings

2 (

CC

CT

and

Duc

t Bur

ner)

Eco

nom

ic A

naly

sis

Det

ail

Ass

umpt

ions

!lnslalled Cas I

46,1

59~0O4 $OOOs

Fix

ed C

harg

e0 2004$ per kW

-mo

Insu

ranc

e C

ost

Inst

alle

d C

ost

324

2004

$/k

WA

xed

O&

M75 2004$ per kW

-mo

Gas

Tra

nspo

rt

Proj

ect C

apac

ity14

2.E

scal

atio

n R

ates

General Inflation

Hea

t Rat

e44

4B

tulk

Wh

Fix

ed O

&M

0 percent

Opt

ion

Val

ueGas Usage Rate

25.

ooos

dttV

day

Tra

nspo

rtat

ion

0 percent

. .

138.48 2004 $OOOs

00 2004

$Idt

hlda

y0 percent

000 2004 $ooos

Nom

inal

Dis

coun

tR

eal D

isco

unt

2 percent

5 percent

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Fix

ed O

pera

ting O

ptio

n N

et Tota

l Pro

ject

Ene

my

Proi

ect

Fixe

d C

hrTotal Costs

Fixe

d G

tran

s Pr

Tax

Insu

r.T

otal

CC

osts

Mem

in

Val

uePr

oect Benefit

otal Variable Costs

Cos

ts(G

Wh)

($0

00s)

($0

00s)

($00

05)

($lM

Wh)

($0

00s)

($0

005)

($0

005)

($0

005)

($0

00s)

($l

MW

h) ($

0005

) ($

0005

) ($

0005

) ($

000s

) ($

lMW

h) (

$000

s) (

$lM

Wh)

($0

00s)

($lM

Wh)

4 20

08 731.4 837

6 ~O

837

6 11

.5 3

,363

0 564

. 156 408

3 5.

12,458 6

491

2,25

1 (3

,716

) (5

.1) 27

821

38.0 40,

286

55.

2012

ji7.4

S7

5

. ...

, "'.

. .. 7~

57S

'" ""

9:7'

.,...

.. .3

,iEJ5

. . h

..... ...

(i .

., "4

77..

""'1

75.' .'.'

.

438

. , ..

.5:

7. .

....,.

.()

13.

...

~U33

..'

2;53

4

'. .".

(346

f."'.

"(0:

4) ..

. 3f

399

'.. ' 40

.4. ...

. . '

43~

412'

" ".

'55:

a

10 2014 781.6 119

6 0 7

196

9.2 401

5 434 . 186 4

635

5.9 11,832 10210 2688 1

066

1.4 32

876

42.1 44,

708

57.

12 2016 798.7

6,85

1 0 6

851

. 8.6

4,26

0 39

0 197 4

848

6.1 11

699 11481 2

852

2,63

4 3.

3 j5

010

43.8 46,

708

58.

14.2

018

. '

807:

6

'.. "

6;49

3

..'."

". "

".'.

0 .

493.

,.

.. '. 8~

O....

". 4;51'9.

"'. .

0".

" .

347.

' ~iC)9'" ..5~

oj6.

. 0. ".

t3.~

f . ,.

.. n;

569

. .'

fi)3!i." 3

025.

."4;

195.

' .

5:2'" "

36;8

84 .'

.

,.. ' 48

;453

00, .

60:0

16 2020 829.8 617

1 0

6,17

1 7.4 479

5 30

4 22

2 5,

321

6.4 11,491 14248 3

209

5,96

6 7.

2 39,47

0 47

.6 50

961

61.

18 2

022

842.4 5.83

3 0

5,83

3 6.

9 5,

087

260 . 236

. 5.58

3 6.6 11.

416

15.799 3

405

7,78

8 9.2 41

721

49.5 53

137

63.

20 2

024

877.

557

a 5,55

7 6:

3 5~

396 0 211

. 250

5~86

3 6.

. 1

420

17,5

68 3

,612 . 9,760 11.1

. .

45.2

41 5

1.. 5~,66

1 .6

4.

Yea

r

Net

Pre

sent

Val

ue 7

4,09

1N

omin

alle

veliz

ed C

ost (

$IM

Wh)


/MW

h)

091

083

620

719

43,4

2211

7,51

392

,691

822

(0)

308

932

426,

445

(0.

(0.

40.

32.

55.

45.

= ~

(JC

:/ =

-

N 8

:Q

f""t

o-Q

~01

Aur

ora

Res

ults

(in

crea

sing

IHR

).xl

s

AV

IST

JIN

'

. ""' R

AFT

500/0 of C

oyot

e S

prin

gs 2

(C

CC

T a

nd D

uct B

urne

r)E

cono

mic

Ana

lysi

s D

etai

l

Ass

umpt

ions

Iins

talle

d C

ost

116

923

2004

$oo

osF

ixed

Cha

rge

0 2004$ per kW

-m

oIn

sura

nce

Cos

t3~

0.77 2004 $ooos

Inst

alle

d C

ost

822

2004

$/k

WF

ixed

O&

M75 2004$ per kW

-mo

Gas

Tra

nspo

rt00 2004

$Idt

hlda

y

Pro

ject

Cap

acity

142.

Esc

alat

ion

Rat

esGeneral Inflation

0 percent

Hea

t Rat

e44

4B

tu/k

Wh

Fix

ed O

&M

0 percent

Opt

ion

Val

ue000 2004 $ooos

Gas

Usa

ge R

ate

25.

ooos

dth

lday

Tra

nspo

rtat

ion

0 percent

Nom

inal

Dis

coun

tR

eal D

isco

unt

2 percent

5 percent

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Fix

ed O

pera

ting O

ptio

n N

et Tota

l Pro

ject

Ene

rav

Proj

ect

Fix

ed C

hrTotal Costs

Fixe

d G

tran

s Pr

Tax

Insu

r.T

otal

CC

osts

Mar

ain

Val

uePr

oec

t Ben

efi

tT

otal

Var

iabl

e C

ost

Cos

ts

(GW

h) (

$000

5) (

$000

s) ($

000s

) ($

lMW

h) (

$000

5) (

$000

5) (

$000

5) (

$000

5) (

$000

5) ($

lMW

h) ($

000s

) ($

0005

) ($

000s

) ($

0005

) ($

lMW

h) (

$000

5) (

$lM

Wh)

($0

005)

($lM

Wh)

2 2006 822.5 2021

5 0 20

215

24.6

3,1

70 0

1.5

39 3

72 5

.081

6.2 25296 6

235

2.12

2 (1

6,93

8) (

20.6) 25.57

3 31

.1 50,

869

61.

!::::

:;,

;i*::;

:::!~

~~:~

~:I:

~U~;

i~:~

:~~:

jEr=

~:~C

IC~;

:lC~1

~~C

~~~~

;1:;T

~!~w

=;r

;:;i:

8 2012 785.9 16,48

1 0 16

481

21.0

3.7

85 0

1,2

09 4

44 5

,438

6.9 21.919 19

930

2.53

4 54

5 0.7 28

812

36.7 50,

731

64.

10 2014 692.6 15,22

7 0 15,22

7 22

.0 4

.015

0 1

099

471

5,58

6 8.1 20.813 21

958

. 268

8 3.

832

5.5 26

759

38.6 47.

572

68.

12 2

016

724.3 1423

1 0 14

231

19.6

4,2

60

989

500

5,74

9 7.9 19

980

23,444 2

852

6,31

5 8.7 30

016

41.4 49.

996

. 69.

2018

.66

0:6

. '

13;0

24."

'.

'" .."

...'.

13,0

24"

"'19

.f ..

' "

4;51

.9' ,," "'

0". '"

"

aiff

'n. .

"".5

31..

. .

5;1)

'29

,. ,. ti.

"". .

8;953.' .

0 . 23

,72:

i

--

3i)2

5'

. "

';795

. ..

... ' ff

a

. '.

865

.

. .

4ii.

.... 47;8i8..' .. i2

.

16 2

020

711.1 1202

5 0 12,02

5 16

.9 4

,795

769

563

6.12

7 8.6 18,152 26543 3209 11

600

16.3 32.04

1 45

.1 50,

193

70.

18 2

022

798.2 1113

4 0 11

134

13.9

5.0

87 0

. 65

9 59

7., 6.34

3 7.

17,477 2591

9 3,405 11

847

14.8 37.

440

' 46.9 54

918

68.

20 2

024

975.7 10.59

5 0 10

595

10.9

5.3

96

549

634

6,57

9 . 6.7 17.174 188

859

3,61

2 17

5,29

7 17

9.7 50

118

51.4 67

352

69.

Yea

r

Net

Pre

sent

Val

ue 1

60,8

01N

omin

al L

evel

ized

Cos

t ($/

MW

h)R

eal L

evel

ized

Cos

t ($/

MW

h)

0 160

801

083

704

353

140

213

941

189,

119

24,8

22(0

)27

8,20

149

2,14

2

21.

17.

7;2

(0.

(0.

37.

30.

66.

54.

~ ~

IJC

I =

-... 0'"

N ..

.

~....

.

0 ~

04 A

uror

a R

esul

ts (

IRP

Pric

es).

xls

A V

IST

AIN

T'

"'R

AFT

500/

0 of

Coy

ote

Spr

ings

2 (

CC

CT

and

Duc

t Bur

ner)

Eco

nom

ic A

naly

sis

Det

ail

jlnst

alle

d C

ost

Inst

alle

d C

ost

Pro

ject

Cap

acity

Hea

t Rat

eGas Usage Rate

0 percent

0 percent

Ass

umct

ions

Insu

ranc

e C

ost

Gas

Tra

nspo

rtG

ener

al In

flatio

nO

ptio

n V

alue

349.15 2004 $ooos

00 2004 $/

dth/

day

0 percent

000 2004 $000$

Nom

inal

Dis

coun

tR

eal D

isco

unt

2 percent

5 percent

116385 2004 $Ooos

818 2004 $/kW

142.3 MW

444 BtulkWh

25.4 ooOs dth/day

Axed Charge

Fix

ed O

&M

Esc

alat

ion

Rat

esF

ixed

O&

MT

rans

port

atio

n

0 2004$ per kW

-mo

75 2004$ pe

r kW

-mo

Fix

ed C

osts

ital R

ecov

ean

d M

isce

llane

ous

erat

ions

& M

aint

enan

ce T

otal

Axe

d O

pera

ting O

ptio

n N

et Tota

l Project

Ene

rgy

Proi

ect

Fix

ed C

hrTotal Costs

Fixe

d G

tran

s Pr

Tax

Insu

r.T

otal

st

s C

osts

Man

:Jln

Val

uePr

oec

t Ben

efit

Total Variable Costs

Cos

ts

(GW

h) (

$000

s) ($

0005

) .($

0005

) ($

lMW

h) (

$000

5) (

$000

5) (

$000

5) (

$000

5) (

$000

5) ($

lMW

h) ($

0005

) ($

0005

) ($

0005

) ($

0005

) ($

lMW

h) (

$000

5) (

$lM

Wh)

($oO

Os)

($lM

Wh)

. ~ .

..~

.'~ \i.

~m.iW

;:k

~;M

it~~~

w.a

');;;

i~;~

:;f?:

;t1J)

j;,~~

$~~~

;'~\i*

;J~J

if?i

~~;~

~~~~

~f~~

~lf.

!lI)

~~(~

;;)Jh

!\~i

G;;;

! t!

~j~i

~"~~

~~1i

... ;.

.

~; ~%,j)t~~ ;~N~t; ~;;t~:M:f;jf#ktZ!"jd.~;j~*w:~~~j~!i1j\i~:WJ:It,:m~.M

'.ffi

~~~~#

~ sjjf

~~:J

~B3i

t~~~

~~

~~;~

~t_~

~ ~~

-~~;

;j~~;

~i8 2012 785.

16,4

12

16~4

12 2

0.9

3,78

5 0

1,20

3 442 5

431

6.9 21

842 19930 253

4 62

1 0.

. 28,81

2 36

.7 50

654

64.

::::"

. .

:;::::'

::::

::::!

' ::,~:

l'

' ".

. .

:!':;

1;:"

'i'~;

:i!')~

:r~W

:':::;~~

'

:'i/;m

~~;P

2:::

t1;%

f(0-

' :. . 99

t':'~

?~~1

;)~:

~;,:(

f8':;

N~"

+4'

~~~~

1~04

5

'!"

:;503

?",f

t,1f~

~Jji7

'::6~

~r~1

~~2:f

2!~

~~1

2B"';~

~1':;

)Y2 ~

if'

:!;~

~Fc:

' ~:2

340~

WE

j~~:

~~:3

:' "

!rr- ~

~i!;

';j.

'~.!

!!It

0J:

O~~

Ii~~

~g. 1

~tf

2Y.~

8j:it

8::

,.. ,.. :...

. :. '

. :::;

'.:':::"

.. .

. ,. .

,,::,:

':~:: :l.

.

,..

,:;,;:

,~:i~

r~",1

j:J;;.

::::,.

;,.:::

::.,::

~... ".

,:",-

,,;,,;

,:::.

. .. .

:;;;;~

~:;..

:""

.,:;

",:"

,(,';

~:"':

::

:",g

.;i',:

;:fi~

.

':.:"

.

f.,~

t*",

;;::"

;:&#l

'1".;,,

,.:,'

W~"

;;'~1

"':;o

!"~~

""""

i'!'+

"~-,:,

.."

.,:;

,;..,.

.:,,,

~,.

;;f:"

';':t.

:.:.

. ,. /

;':

:::"-

::':;:

:.:'

,",:"

",,#

.~

u....

;;:.

~, :)

::i!

S#.:~

!JI:

\, ,

:~,.

i1'.;

~:oi

i~s-

:.:-;

,, .;~

j~::!

""""

.....*

,.'..

,.u

.:.

?:*-

:p.;S

i:;.-

.,. ,

.

10 2

014

692.6 15,16

4 0 15

164

21.9 401

5 0 1

094

469

5,57

9 8.1 20,743 21958 2

688

3,90

3 5.6 26

759

38.6 47,

501

68.

12 2

016

724.3 14.17

3 0 14,17

3 19

.6 426

0 98

5 49

8 5.

742

7.9 19,

915

23,444 2852 6

380

8.8 30

016

41.4 49,

931

68.

14 2

018

660.6 12

971

0 12,97

1 19

.6 451

9 875 528

. 5,92

3 9.

0 .

894

23,7

2302

5 7,

854

11.9 28

865

43.7 . 47,

759

. 72.

2020

"" '

1;97

8

'" .. "

"

;978

".".

.'16

.8.' "

4;79

5.".

. ""

'0.. .".

" 766-

." . 56

0' -

..' i

iG .,

18;

099

... 2

6~54

.

" ,.

'

209.

.. T

1)5S

:f".

' 16.

. 32;041

'" .,.

. 4s:

f . '

iio;i3

9..'.

.' ir

is

18 2

022

798.2 1109

2 0 11.09

2 13

.9 5

,087

65

6 59

4 6,

337

7.9 17

429

25,9

19 3,

405 11

895

14.9 37

440

. 46.9 54

870

68.

20 2

024

975.7 10,55

8 0 10

558

10.8

5.3

96

547

631

6,57

4 6.7 17,132 188

859

3.61

2 17

5,33

9 17

9.7 50,17

8 51.4 67

310

69.

Yea

r

Nel

Pre

sent

Val

ue 1

5962

0N

omin

al L

evel

ized

Cos

t ($/

MW

h)R

eal L

evel

ized

Cos

t ($/

MW

h)

0 159

620

083

0 11

650

333

53,0

6621

268

618

7.86

482

226

755

048

0,23

6

22.

18.

37.

30.

67,

. 54.

trj

~ ~

fJC

I =

-

~ -

.

N s

:1"

+

0 ~

04 A

uror

a R

esul

ts (

IRP

Pric

es).

xls