2000 Annual Report.pdf

THIS FILING IS (CHECK ONE BOX FOR EACH ITEM)
Item 1:An initial (Original)OR O Resubmission No.Form ApprovedSubmissionRECEIVEDOMBNo.1902-0021FILEDO(Expires 11/30/2001)Item 2:An Original Signed Form OR O Conformed Copy
200\APR 30 PM 3:37
iDAND PUBLICUTILITIESCOMMISSION
FERC Form No.1:ANNUAL REPORT OF MAJOR ELECTRICUTILITIES,LICENSEES AND OTHERS
This report is mandatory under the Federal Power Act,Sections 3,4(a),304 and 309,and 18 CFR 141.1.Failure to report may result in criminal fines,civil penalties and othersanctionsasprovidedbylaw.The Federal Energy Regulatory Commission does notconsiderthisreporttobeofaconfidentialnature.
Exact Legal Name of Respondent(Company)Year of ReportIdahoPowerCompanyDec.31,2000
FERC FORM No.1 (REV.12-98)
Deloitte &Touche LLP
Suite 1800
101 South Capitol Boulevard
Boise,idaho 83702-5987
Tel:[phone]
Fax:[phone]
www.us.deloitte.com Deloitte
&Touche
INDEPENDENT AUDITORS'REPORT
Idaho Power Company
Boise,Idaho
We have auditedthe balance sheet-regulatorybasis of Idaho Power Companyas of December31,2000,
and the related statements of income-regulatory basis,retainedearnings-regulatorybasis,and cash
flows-regulatory basis for the year ended December31,2000,included on pages 110 through 123 of theaccompanyingFederalEnergyRegulatoryCommissionForm1.These fmancial statements are theresponsibilityoftheCompany's management.Our responsibility is to express an opinion on thesefmancialstatementsbasedonouraudit.
We conducted our audit in accordance with auditing standards generally accepted in the United States ofAmerica.Those standards require that we plan and perform the audit to obtain reasonable assuranceaboutwhetherthefmancialstatementsarefreeofmaterialmisstatement.An audit includes examining,
on a test basis,evidencesupporting the amounts and disclosures in the financial statements.An audit
also includes assessing the accounting principles used and significant estimates made by management,aswellasevaluatingtheoverallfmancialstatementpresentation.We believethat our audit provides a
reasonable basis for our opinion.
As discussed in Note 1,these financial statements were preparedin accordance with the accountingrequirementsoftheFederalEnergyRegulatoryCommissionassetforthinitsapplicableUniform
System of Accounts and published accounting releases,which is a comprehensivebasis of accountingotherthanaccountingprinciplesgenerallyacceptedintheUnitedStatesofAmerica.
In our opinion,such fmancial statements present fairly,in all material respects,the assets,liabilities andproprietarycapitalofIdahoPowerCompanyasofDecember31,2000,and the results of its operations
and its cash flows for the year ended December31,2000,in accordance with the accountingrequirementsoftheFederalEnergyRegulatoryCommissionassetforthinitsapplicableUniform
System of Accounts and published accounting releases.
This report is intendedsolely for the information and use of the Board of Directors and management ofIdahoPowerCompanyandforfilingwiththeFederalEnergyRegulatoryCommissionandisnot
intended to be and should not be used by anyone other than these specifiedparties.
February 1,2001
DeloitteToucheTohmatsu
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INSTRUCTIONSFOR FILING THE
FERC FORM NO.1
GENERAL INFORMATION
I.Purpose
This form is a regulatory support requirement (18 CFR 141.1).It is designed to collect financial andoperationalinformationfrommajorelectricutilities,Licensees and others subject to the jurisdiction of theFederalEnergyRegulatoryCommission.This report is also secondarily considered to be a nonconfidential public useformsupportingastatisticalpublication(Financial Statistics of Selected Electric Utilities),published by theEnergyInformationAdministration.
II.Who Must Submit
Each major electric utility,licensee,or other,as classified in the Commission's Uniform System of AccountsPrescribedforPublicUtilitiesandLicenseesSubjecttotheProvisionsofTheFederalPowerAct(18 CFR 101),mustsubmitthisform.
Note:Major means having,in each of the three previous calendar years,sales or transmission service thatexceeds
one of the following:
(1)one million megawatt hours of total annual sales,
(2)100 megawatt hours of annual sales for resale,
(3)500 megawatt hours of annual power exchanges delivered,or(4)500 megawatt hours of annual wheeling for others (deliveries plus Losses).
III.What and Where to Submit
(a)Submit this form electronically through the Form 1 Submission Software and an original and six (6)conformed paper copies,properly filed in and attested,to:Office of the Secretary
Federal Energy Regulatory Commission
888 First Street,NE.
Room lA
Washington,DC 20426
Retain one copy of this report for your files.
Include with the original and each conformed paper copy of this form the subscription statement required by 18C.F.R.385.2011(c)(5).Paragraph (c)(S)of 18 C.F.R.385.2011 requires each respondent submitting dataelectronicallytofileasubscriptionstatingthatthepapercopiescontainthesameinformationasthe electronicfiling,that the signer knows the contents of the paper copies and electronic filing,and that the contents asstatedinthecopiesandelectronicfilingaretruetothebestknowledgeandbeliefofthesigner.(b)Submit,immediately upon publication,four (4)copies of the Latest annual report to stockholders and anyannualfinancialorstatisticalreportregularlypreparedanddistributedtobondholders,security analysts,orindustryassociations.(Do not include monthly and quarterly reports.Indicate by checking the appropriate box onPage4,List of Schedules,if the reports to stockholders will be submitted or if no annual report to stockholdersisprepared.)Mail these reports to:
Chief Accountant
Federal Energy Regulatory Commission
888 First Street,NE.
Washington,DC 20426
(c)For the CPA certification,submit with the original submission,or within 30 days after the filing date forthisform,a Letter or report (not applicable to respondents classified as Class C or Class D prior to January 1,1984):
(i)Attesting to the conformity,in all material aspects,of the below listed (schedules and)pages withtheCommission's applicable Uniform Systems of Accounts (including applicable notes relating thereto and the ChiefAccountant's published accounting releases),and(ii)Signed by independent certified public accountants or an independent Licensed public accountantcertifiedorLicensedbyaregulatoryauthorityofaStateorotherpoliticalsubdivisionoftheU.S.(See 18 CFR41.10-41.12 for specific qualifications.)
FERC FORM NO.1 (REV.12-99)Page i
GENERAL INFORMATION (continued)
III.What and Where to Submit (Continued)
(c)Continued
Reference
Schedules Pages
ComparativeBalance Sheet 110-113
Statement of Income 114-117
Statement of Retained Earnings 118-119
Statement of Cash Flows 120-121
Notes to Financial Statements 122-123
When accompanying this form,insert the Letter or report immediately following the cover sheet.When submitting
after the filing date for this form,send the letter or report to the office of the Secretary at the address
indicated at III (a).
Use the following format for the Letter or report unless unusual circumstances or conditions,explained in
the Letter or report,demand that it be varied .Insert parenthetical phrases only when exceptions are reported.
In connection with our regular examination of the financial statements of for the year ended on
which we have reported separately under date of .We have also reviewed schedules
of FERC Form No.1 for the year filed with the Federal Energy Regulatory
Commission,for conformity in all material respects with the requirements of the Federal Energy Regulatory
Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.Our review
for this purpose included such tests of the accounting records and such other auditing procedures as we considered
necessary in the circumstances.
Based on our review,in our opinion the accompanying schedules identified in the preceding paragraph (except as
noted below)conform in all material respects with the accounting requirements of the Federal Energy Regulatory
Commission as set forth in its applicable Uniform system of Accounts and published accounting releases.
State in the letter or report,which,if any,of the pages above do not conform to the Commission's
requirements.Describe the discrepancies that exist.
(d)Federal,State and Local Governments and other authorized users may obtain additional blank copies to meet
their requirements free of charge from:
Public Reference and Files Maintenance Branch
Federal Energy Regulatory Commission
888 First Street,NE.Room 2A ES-1
Washington,DC 20426
[phone]
IV.When to Submit
Submit this report form on or before April 30th of the year following the year covered by this report.
V.Where to Send Comments on Public Reporting Burden
The public reporting burden for this collection of information is estimated to average 1,217 hours per
response,including the time for reviewing instructions,searching existing data sources,gathering and maintaining
the data needed,and completing and reviewing the collection of information.Send comments regarding this burden
estimate or any aspect of this collection of information,including suggestions for reducing this burden,to the
Federal Energy Regulatory Commission,888 First Street N.E.,Washington,DC 20426 (Attention:Mr.Michael Miller,
CI-1);and to the Office of Information and Regulatory Affairs,Office of Management and Budget,Washington,DC
20503 (Attention:Desk Officer for the Federal Energy Regulatory Commission).No person shall be subject to any
penalty if this collection of information does not display a valid control number.(44 U.S.C.3512(a)).
FERC FORM NO.1 (REV.12-99)Page ii
GENERAL INSTRUCTIONS
I.Prepare this report in conformity with the Uniform System of Accounts (18 CFR 101)(U.S.of A.).Interpret
all accounting words and phrases in accordance with the U.S.of A.
II.Enter in whole numbers (dollars or MWH)only,except where otherwise noted.(Enter cents for averages and
figures per unit where cents are important.The truncating of cents is allowed except on the four basic financial
statements where rounding is required.)The amounts shown on all supporting pages must agree with the amounts
entered on the statements that they support.When applying thresholds to determine significance for reporting
purposes,use for balance sheet accounts the balances at the end of the current reporting year,and use for
statement of income accounts the current year's amounts.
III,Complete each question fully and accurately,even if it has been answered in a previous annual report.Enter
the word "None"where it truly and completely states the fact.
IV.For any page(s)that is not applicable to the respondent,omit the page(s)and enter "NA,""NONE,"or "Not
Applicable"in column (d)on the List of Schedules,pages 2,3,and 4.
V.Enter the month,day,and year for all dates.Use customary abbreviations.The "Date of Report"included in
the header of each page is to be completed only for resubmissions (see VII.below).The date of the resubmission
must be reported in the header for all form pages,whether or not they are changed from the previous filing.
VI.Generally,except for certain schedules,all numbers,whether they are expected to be debits or credits,must
be reported as positive.Numbers having a sign that is different from the expected sign must be reported by
enclosing the numbers in parentheses.
VII.For any resubmissions,submit the electronic filing using the Form 1 Submission Software and an original and
six (6)conformed paper copies of the entire form,as well as the appropriate number of copies of the subscription
statement indicated at instruction III (a).Resubmissions must be numbered sequentially on the cover page of the
paper copies of the form.In addition,the cover page of each paper copy must indicate that the filing is a
resubmission.Send the resubmissions to the address indicated at instruction III (a).
VIII.Do not make references to reports of previous years or to other reports in lieu of required entries,except
as specifically authorized.
IX.Wherever (schedule)pages refer to figures from a previous year,the figures reported must be based upon
those shown by the annual report of the previous year,or an appropriate explanation given as to why the different
figures were used.
DEFINITIONS
I.Commission Authorization (Comm.Auth.)--The authorization of the Federal Energy Regulatory Commission,or any
other Commission.Name the commission whose authorization was obtained and give date of the authorization.
II.Respondent --The person,corporation,licensee,agency,authority,or other Legal entity or instrumentality in
whose behalf the report is made.
FERC FORM NO.1 (REV.12-99)Page iii
EXCERPTS FROM THE LAW
Federal Power Act,16 U.S.C.791a-825r)
"Sec.3.The words defined in this section shall have the following meanings for purposes of this Act,to wit:
...(3)"Corporation"means any corporation,joint-stock company,partnership,association,business trust,
organized group of persons,whether incorporated or not,or a receiver or receivers,trustee or trustees of any of
the foregoing.It shalt not include 'municipalities,as hereinafter defined;
(4)"Person"means an individual or a corporation;
(5)"Licensee"means any person,State,or municipality Licensed under the provisions of section 4 of this Act,
and any assignee or successor in interest thereof;
(7)"Municipality"means a city,county,irrigation district,drainage district,or other political subdivision
or agency of a State competent under the Laws thereof to carry an the business of developing,transmitting,
unitizing,or distributing power;..."
(11)"Project"means a complete unit of improvement or development,consisting of a power house,all water
conduits,all dams and appurtenant works and structures (including navigation structures)which are a part of said
unit,and all storage,diverting,or forebay reservoirs directly connected therewith,the primary line or Lines
transmitting power therefrom to the point of junction with the distribution system or with the interconnected
primary transmission system,all miscellaneous structures used and useful in connection with said unit or any part
thereof,and all water rights,rights-of-way,ditches,dams,reservoirs,Lands,or interest in Lands the use and
occupancy of which are necessary or appropriate in the maintenance and operation of such unit;
"Sec.4.The Commission is hereby authorized and empowered:
(a)To make investigations and to collect and record data concerning the utilization of the water 'resources of
any region to be developed,the water-power industry and its relation to other industries and to interstate or
foreign commerce,and concerning the location,capacity,development costs,and relation to markets of power sites;
..to the extent the Commission may deem necessary or useful for the purposes of this Act."
"Sec.304.(a)Every Licensee and every public utility shall file with the Commission such annual and other
periodic or special reports as the Commission may be rules and regulations or other prescribe as necessary or
appropriate to assist the Commission in the proper administration of this Act.The Commission my prescribe the
manner and form in which such reports shalt be made,and require from such persons specific answers to all
questions upon which the Commission may need information.The Commission may require that such reports shall
include,among other things,full information as to assets and Liabilities,capitalization,net investment,and
reduction thereof,gross receipts,interest due and paid,depreciation,and other reserves,cost of project and
other facilities,cost of maintenance and operation of the project and other facilities,cost of renewals and
replacement of the project works and other facilities,depreciation,generation,transmission,distribution,
delivery,use,and sale of electric energy.The Commission may require any such person to make adequate provision
for currently determining such costs and other facts.Such reports shall be made under oath unless the Commission
otherwise specifies."
"Sec.309.The Commission shall have power to perform any and all acts,and to prescribe,issue,make,and rescind
such orders,rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act.
Among other things,such rules and regulations may define accounting,technical,and trade terms used in this Act;
and may prescribe the form or forms of all statements,declarations,applications,and reports to be filed with the
Commission,the information which they shall contain,and the time within which they shall be filed..."
General Penalties
"Sec.315.(a)Any licensee or public utility which willfully fails,within the time prescribed by the Commission,
to comply with any order of the Commission,to file any report required under this Act or any rule or regulation of
the Commission thereunder,to submit any information of document required by the Commission in the course of an
investigation conducted under this Act ...shall forfeit to the United States an amount not exceeding $1,000 to be
fixed by the Commission after notice and opportunity for hearing..."
FERC FORM NO.1 (ED.12-91)Page iv
FERC FORM NO.1:
ANNUAL REPORT OF MAJOR ELECTRIC UTILITIES,LICENSEES AND OTHER
IDENTIFICATION
01 Exact Legal Name of Respondent 02 Year of Report
Idaho Power Company Dec.31,2000
03 Previous Name and Date of Change (if narne changed duringyear)
04 Address of Principal Office at End of Year (Street,City,State,Zip Code)
1221 W Idaho Street,P.O.Box 70 Boise,ID 83707-0070
05 Name of Contact Person 06 Title of Contact Person
Darrel Anderson VP of Finance &Treasurer
07 Address of Contact Person (Street,City,State,Zip Code)
1221 W Idaho Street,P.O.Box 70 Boise,ID 83707-0070
08 Telephone of Contact Person,lncluding 09 This Report Is 10 Date of ReportAreaCode(1)O An Original (2)A Resubmission (Mo,Da,Yr)
[phone] 04/30/2001
ATTESTATION
The undersigned officer certifies that helshe has examined the accompanying report:that to the best of his/her knowledge,information,and belief,all statements of fact contained in the accompanying report are true and the accompanying report is a correct statement of the business andaffairsoftheabovenamedrespondentinrespecttoeachandeverymattersetforththereinduringtheperiodfromandincludingJanuary1toandincludingDecember31oftheyearofthereport.
01 Name 03 Signature 04 Date Signed
(Mo,Da,Yr)
02 T
treelAnderson
04/30/2001
VP of Finance &Treasurer
Title 18,U.S.C.1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States anyfalse,fictitious or fraudulent statements as to any matter within its jurisdiction.
FERC FORM No.1 (ED.12-91)Page 1
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
LIST OF SCHEDULES (Electric Utility)
Enter in column (c)the terms "none,""not applicable,"or "NA,"as appropriate,where no information or amounts have been reported for
certain pages.Omit pages where the respondents are "none,""not applicable,"or "NA".
Line Title of Schedule Reference Remarks
No.Page No.
(a)(b)(c)
1 General information 101
2 Control Over Respondent 102
3 Corporations Controlled by Respondent 103
4 Officers 104
5 Directors 105
6 Security Holders and Voting Powers 106-107
7 Important Changes During the Year 108-109
8 Comparative Balance Sheet 110-113
9 Statement of Income for the Year 114-117
10 Statement of Retained Earnings for the Year 118-119
11 Statement of Cash Flows 120-121
12 Notes to Financial Statements 122-123
13 Summary of Utility Plant &Accumulated Provisions for Dep,Amort &Dep 200-201
14 Nuclear Fuel Materials 202-203 None
15 Electric Plant in Service 204-207
16 Electric Plant Leased to Others 213 None
17 Electric Plant Held for Future Use 214
18 Construction Work in Progress-Electric 216
19 Construction Overheads-Electric 217
20 General Description of Construction Overhead Procedure 218
21 Accumulated Provision for Depreciation of Electric Utility Plant 219
22 Nonutility Property 221
23 Investment of Subsidiary Companies 224-225
24 Materials and Supplies 227
25 Allowances 228-229
26 Extraordinary Property Losses 230
27 Unrecovered Plant and Regulatory Study Costs 230
28 Other Regulatory Assets 232
29 Miscellaneous Deferred Debits 233
30 Accumulated Deferred IncomeTaxes 234
31 Capital Stock 250-251
32 Cap Stk Sub,Cap Stk Liab for Con,Prem Cap Stk &Inst Recd Cap Stk 252
33 Other Paid-in Capital 253
34 Discount on Capital Stock 254
35 Capital Stock Expense 254
36 Long-Term Debt 256-257
FERC FORM NO.1 (ED.12-96)Page 2
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
LIJT OF SCHEDULES (Electric Utility)(continued)
Enter in column (c)the terms "none,""not applicable,"or "NA,"as appropriate,where no information or amounts have been reported forcertainpages.Omit pages where the respondents are "none,""not applicable,"or "NA".
Line Title of Schedule Reference RemarksNo.Page No.(a)(b)(c)
37 Reconciliationof Reported Net Income with Taxable Inc for Fed inc Tax 261 ,
38 Taxes Accrued,Prepaid and Charged During the Year 262-263 I
39 Accumulated Deferred Investment Tax Credits 266-267
40 Other Deferred Credits 269
41 Accumulated Deferred Income Taxes-Accelerated Amortization Property 272-273
42 Accumulated Deferred Income Taxes-Other Property 274-275
43 Accumulated Deferred Income Taxes-Other 276-277
44 Other Regulatory Liabilities 278
45 Electric Operating Revenues 300-301
46 Sales of Electricity by Rate Schedules 304I
47 Sales for Resale 310-311
48 i Electric Operation and Maintenance Expenses 320-323
49 Numberof Electric Department Employees 323
50 Purchased Power 326-327
51 Transmission of Electricity for Others 328-330
52 Transmission of Electricity by Others 332
53 Miscellaneous General Expenses-Electric 335
54 Depreciation and Amortization of Electric Plant 336-337
55 Particulars Concerning Certain income Deduction and Int Charges Accnts 340
56 Regulatory Commission Expenses 350-351
57 Research,Development and Demonstration Activities 352-353
58 Distribution of Salaries and Wages 354-355
59 Common Utility Plant and Expenses 356 None
60 Electric Energy Account 401
61 Monthly Peaks and Output 401
62 Steam Electric Generating Plant Statistics (Large Plants)402-403
63 Hydroelectric Generating Plant Statistics (Large Plants)406-407
64 Pumped Storage Generating Plant Statistics (Large Plants)408-409 None
65 Generating Plant Statistics (Small Plants)410-411
66 Transmission Line Statistics 422-423
FERC FORM NO.1 (ED.12-96)Page 3
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
LIST OF SCHEDULES (Electric Utility)(continued)
Enter in column (c)the terms "none,""not applicable,"or "NA,"as appropriate,where no information or amounts have been reported for
certain pages.Omit pages where the respondents are "none,""not applicable,"or "NA".
Line Title of Schedule Reference Remarks
No.PageNo.
(a)(b)(c)
67 Transmission Lines Added During Year 424-425
68 Substations 426-427
69 Electric Distribution Meters and Line Transformers 429
70 Environmental Protection Facilities 430
71 Environmental Protection Expenses 431
72 Footnote Data 450
Stockholders'Reports Check appropriate box:
Four copies will be submitted
O No annual report to stockholders is prepared
FERC FORM NO.1 (ED.12-96)Page 4
Name of Respondent This Report Is:Date of Report Year of Report
Idaho Power Company (1)An Original (Mo,Da,Yr)
(2)A Resubmission 04/30/2001 Dec.31,2000
GENERAL INFORMATION
1.Provide name and title of officer having custody of the general corporate books of account and address ofofficewherethegeneralcorporatebooksarekept,and address of office where any other corporate books of account
are kept,if different from that where the general corporate books are kept.
Darrel Anderson Vice President,Finance and Treasurer,Idaho Power Company
1221 W.Idaho Street,P.O.Box 70,Boise,Idaho 83707-0070
2.Provide the name of the State under the laws of which respondent is incorporated,and date of incorporation.
If incorporated under a special law,give reference to such law.If not incorporated,state that fact and give the typeoforganizationandthedateorganized.
Idaho,June 30,1989
3.If at any time during the year the property of respondentwas held by a receiver or trustee,give (a)name ofreceiverortrustee,(b)date such receiver or trustee took possession,(c)the authority by which the receivership ortrusteeshipwascreated,and (d)date when possession by receiver or trustee ceased.
Not Applicable
4.State the classes or utility and other services furnished by respondentduring the year in each State in which
the respondent operated.
Class of Utility Service State
Electric Idaho
"Oregon
Nevada
5.Have you engaged as the principal accountantto audit your financial statements an accountant who is nottheprincipalaccountantforyourpreviousyear's certified financial statements?
(1)Yes...Enter the date when such independentaccountant was initially engaged:
(2)[X]No
FERC FORM No.1 (ED.12-87)PAGE 101
l
Name of Respondent This Report Is:Date of Report Year of Report
Idaho Power Company (1)An Original (Mo,Da,Yr)
(2)A Resubrnission 04/30/2001 Dec.31,2000
CONTROL OVER RESPONDENT
1.If any corporation,business trust,or similar organization or a combination of such organizations jointly held
control over the repondent at the end of the year,state name of controlling corporation or organization,manner in
which control was held,and extent of control.If control was in a holding company organization,show the chain
of ownership or control to the main parent company or organization.If control was held by a trustee(s),state
name of trustee(s),name of beneficiary or beneficiearies for whom trust was maintained,and purpose of the trust.
Idaho Power Company is a subsidiary of IdaCorp.
IdaCorp owns 100%of Idaho Power Company's Common Stock.
IdaCorp is a public utility Holding Company incorporated effective 10-1-1998
FERC FORM NO.1 (ED.12-96)Page 102
This Page Intentionally Left Blank
Name of Respondent This R ort is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
CORPORATIONS CONTROLLED BY RESPONDENT
1.Report below the names of all corporations,business trusts,and similar organizations,controlled directly or indirectly by respondent
at any time during the year.If control ceased prior to end of year,give particulars (details)in a footnote.
2.If control was by other means than a direct holding of voting rights,state in a footnote the manner in which control was held,naming
any intermediaries involved.
3.If control was held jointly with one or more other interests,state the fact in a footnote and name the other interests.
Definitions
1.See the Uniform System of Accounts for a definition of control.
2.Direct control is that which is exercised without interposition of an intermediary.
3.Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control.
4.Joint control is that in which neither interest can effectively control or direct action without the consent of the other,as where the
voting control is equally divided between two holders,or each party holds a veto power over the other.Joint control may exist by
mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of
control in the Uniform System of Accounts,regardless of the relative voting rights of each party.
Line Name of Company Controlled Kind of Business Percent Voting Footnote
No.Stock Owned Ref.
(a)(b)(c)(d)
1 Direct Control
2 Idaho Energy Resources Company Coal mining and mineral 100%
3 development
4 IDACORP Financial Services,Inc.Acquisition and investments
5 in non-regulated activities
6
7 IDACORP Acquisition LLC Acquisition and investments
8 in non-regulated activities
9
10 idaho Power Resources Corporation Design,consult solar photo-100%no activity in 2000
11 voltaic technology,micro
12 hydroelectric systems and
13 other renewable energy
14 systems to various locations
15
16 Applied Power Corporation Distributor,integrator of
17 sustainable power solutions
18 worldwide;focusing on solar
19 electric applications
20
21 Pathnet/ldaho Equipment,LLC.Develop &distributor of 81%
22 microwave communication
23 services &products
24
25 Idaho Power Diversified Enterprises Company Holding company for non-100%no activity in 2000
26 regulated activities
27
FERC FORM NO.1 (ED.12-96)Page 103
Name of Respondent This Report Is:Date of Report Year of Report(1)QAn Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
OFFICERS
1.Report below the name,title and salary for each e×ecutive officer whose salary is $50,000 or more.An "executiveofficer"of arespondentincludesitspresident,secretary,treasurer,and vice president in charge of a principal business unit,division or function(such as sales,administration or finance),and any other person who performs similar policy making functions.2.If a change was made during the year in the incumbent of any position,show name and total remuneration of the previousincumbent,and the date the change in incumbency was made.
Line 'Title Nameof Ófficer 'SalaryforYearNo(a)(b)(c)
1
2 President and Chief Executive Officer Jan B.Packwood 415,000
3
4 Senior Vice President ,Marketing &Sales Richard Riazzi 250,000
5
6 Sr V P,Administrationr &Chief Financial Officer J.LaMont Keen 250,000
7
8 Vice President,General Counsel and Secretary Robert W.Stahman 165,000
9
10 Vice President,Finance and Treasurer Darrel T Anderson 135,000
11
12 Vice President ,Corporate Services Clifford N.Olson 142,100
13
14 Sr Vice President,Delivery James C.Miller 170,000
15
16 Vice President ,Generation John P Prescott 130,000
17
18 Vice President,Human Resources Marlene K Williams 131,250
19
20 Vice President and Chief Information Officer Bryan A Kearny 150,000
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
FERC FORM NO.1 (ED.12-96)Page 104
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTEDATA
Schedule Page:103 Line No.:4 Column:a
On January 1,2000 Idacorp Financial Services,Inc was transferred from Idaho Power
Company to IdaCorp.IdaCorp is the parent Company of Idaho Power.
Schedule Page:103 Line No.:7 Column:a
On January 1,2000 IdaCorp Acquisition LLC,was transferred from Idaho Power
Company to IdaCorp.IdaCorp is the parent Company of Idaho Power.
Schedule Page:103 Line No.:16 Column:a
On January 1,2000 Applied Power Corporation,was transferred from Idaho Power
Company to IdaCorp.Idacorp is the parent Company of Idaho Power.
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
DIRECTORS
1.Report below the information called for concerning each director of the respondent who held office at any time during the year.Include in column (a),abbreviatedtitlesofthedirectorswhoareofficersoftherespondent.
2.Designate members of the Executive Committee by a triple asterisk and the Chairman of the Executive Committee by a double asterisk.Line Name (and Title)of Director Principal Business AddressNo.(a)(b)
1 Rotchford L.Barker P.O.Box 2080,Cody Wyoming 82414
2
3 Robert D.Bolinder**140 Hearthstone Drive,Boise,Idaho 83702-1720
4
5 Roger L.Breeziey Breezley Investments,3625 U.S.Bancorp Tower,
6 Portland,Oregon 97208
7
8 John B.Carley***2375 N.Towerview Lane,Boise,Idaho 83702
9
10
11 Peter T.Johnson P.O.Box 1591,McCall,Idaho 83638
12
13 Jack K.Lemley Lemley &Associates,Inc.
14 1508 N.13th,Boise,idaho 83702
15
16 Evelyn Loveless Global,Inc.,900 W.Jefferson Street,Boise,Idaho 83702
17
18 Jon H.Miller,Chairman of the Board***P.O.Box 1557,Boise,Idaho 83701
19
20 Peter S.O'Neill O'Neill Enterprises,Inc.
21 871 E.Parkcenter Blvd.,Boise,idaho 83706
22
23 Jan 8.Packwood President and CEO Idaho Power Company,1221 W.Idaho Street,
24 P.O.Box 70,Boise,Idaho 83707-0070
25
26 Robert A.Tinstman 4433 W.Quail Point Court,Boise,Idaho,83703
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
FERC FORM NO.1 (ED.12-95)Page 105
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
SECURITY HOLDERS AND VOTING POWERS
1.Give the names and addresses of the 10 security holders of the respondent who,at the date of the latest closing of the stock book or compilation of
list of stockholders of the respondent,prior to the end of the year had the highest voting powers in the respondent,and state the number of votes which
each would have had the right to cast on that date if a meeting were then in order.If any such holder held in trust,give in a footnote the known
particulars of the trust(whether voting trust,etc.)duration of trust,and principal holders of beneficiary interests in the trust.If the stock book was not
closed or a list of stockholders was not compiled within one year prior to the end of the year,or if since the previous compilation of a List of stockholders,
some other class of security has become vested with voting rights,then show such 10 security holders as of the close of the year.Arrange the names
of the security holders in the order of voting power,commencing with the highest.Show in column (a)the titles of officers and directors included in such
list of 10 security holders.
2.If any security other than stock carries voting rights,explain in a footnote the circumstances whereby such security became vested with voting rights
give other important particulars (details)concerning voting rights of such security.State whether voting right are actual or contingent;if contingent,
describe the contingency.
3.If any class or issue of security has any special privileges in the election of directors,trustees or managers,or in the determination of corporate
action by any method explain briefly in a footnote.
4.Furnish particulars (details)concerning any options warrants,or rights outstanding at the end of the year others to purchase securities of the
respondent or any securities or other assets owned by the respondent,including prices,expiration dates,and other material information relating to
exercise of the options,warrants,or right the amount of such securities or assets so entitled to purchased by any officer,director,associated company,
or of the ten largest security holders.This instruction is inapplicable to convertible securities or to any securities substantially all of which are outstanding
in the hands of the public where the options,warrants,or rights were issued prorata basis.
1.Give the date of the latest closing of the stock 2.State the total number of votes cast at the 3.Give the date and
book prior to end of year,and state the purpose latest general meeting prior to end of year place of such meeting
of such closing:for election of directors of the respondent and Boise,idaho12/31/00 numberof such votes cast by proxy May 11,2000
Total:2,380,289
By Proxy:2,380,289
VOTING SECURITIESLineName(Title)and Address of Security
No.Number of Votes as of (date):12/31/2000HolderTotalCommon Preferred Other
Votes Stock Stock
(a)(b)(c)(d)(e)
4 TOTAL votes of all voting securities 3,302,000 3,152,000 150,000
5 TOTAL number of security holders 1,682 1,603 79
6 TOTAL votes of security holders listed below 278,375 277,700 675
7 Katheryne Maulsby -Meridian Id 43,260 43,260
8 Viola M Greenawalt -Twin Falls id 41,780 41,780
9 Robert &Mary Lynard -Boise,Id 30,760 30,560 200
10 James &Hai Gilbert -Salt Lake City,Ut 29,035 28,560 475
11 Logan &Mary Lanham -Boise,Id 28,200 28,200
12 G Morris Southward -Las Cruces,NM 24,420 24,420
13 Darlene 1 Wilcox -Jerome,Id 20,920 20,920
14 Evertt JoneRuth &John Baird -Gooding,20,000 20,000
15 W Robert Hollowell -Aurora,Co 20,000 20,000
16 John Barid -San Diego,Ca 20,000 20,000
17
18
FERC FORM NO.1 (ED.12-96)Page 106
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
SECURITY HOLDERS AND VOTING POWERS (Continued)
Line Name (Title)and Address of Security Total Common Preferred OtherNo.Holder Votes Stock Stock(a)(b)(c)(d)(e)
19 2 -None
20
21 3-4%preferred stock entitled to 20 vote
22 per share:common stock &7.68%serial
23 preferred entitled to 1 vote per share.
24 If dividends on the 4%shall be accum-
25 ulated and unpaid in an amount
26 equivalent to or exceeding 4 quarterly
27 dividends,the holders are entitled at
28 each succeding annual meeting to elect
29 the smallest number of directors needed
30 to constituee a majority of the Board.
31 The remaining directors to be elected as
32 usual by the shareholders without
33 distinction to class,until all unpaid
34 dividends have been eliminated.
35 If dividends on the serial preferred
36 stock,are unpaid in an amount equal to
37 6 quarterly dividends,the holders are
38 entitled at each succeeding annual
39 meeting to elect 2 directors from among
40 those who would otherwise be elected by
41 shareholders without distinction to clas
42 until all unpaid dividends are eliminate
43
44
45
46
47
48
49
50
51
52
53
FERC FORM NO.1 (ED.12-96)Page 107
Name of Respondent This Report Is:Date of Report Year of Report
idaho Power Company (1)g An Original 04/30/2001 Dec.31,2000
(2)A Resubmission
IM >ORTANTCHANGES DURING THE YEAR
Give particulars (details)concerning the matters indicated below.Make the statements explicit and precise,and number them in
accordance with the inquiries.Each inquiry should be answered.Enter "none,""not applicable,"or "NA"where applicable.If
information which answers an inquiry is givenelsewhere in the report,make a reference to the schedule in which it appears.
1.Changes in and important additions to franchise rights:Describe the actual consideration given therefore and state from whom the
franchise rights were acquired.If acquired without the payment of consideration,state that fact.
2.Acquisition of ownership in other companies by reorganization,merger,or consolidation with other companies:Give names of
companies involved,particulars concerning the transactions,name of the Commission authorizing the transaction,and reference to
Commission authorization.
3.Purchase or sale of an operating unit or system:Give a brief description of the property,and of the transactions relating thereto,
and reference to Commission authorization,if any was required.Give date journal entries called for by the Uniform System of Accounts
were submitted to the Commission.
4.Important leaseholds (other than leaseholds for natural gas lands)that have been acquired or given,assigned or surrendered:Give
effective dates,lengths of terms,names of parties,rents,and other condition.State name of Commission authorizing lease and give
reference to such authorization.
5.Important extension or reduction of transmission or distribution system:State territory added or relinquished and date operations
began or ceased and give reference to Commission authorization,if any was required.State also the approximate number of
customers added or lost and approximate annual revenues of each class of service.Each natural gas company must also state major
new continuing sources of gas made available to it from purchases,development,purchase contract or otherwise,giving location and
approximate total gas volumes available,period of contracts,and other parties to any such arrangements,etc.
6.Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term
debt and commercial paper having a maturity of one year or less.Give reference to FERC or State Commission authorization,as
appropriate,and the amount of obligation or guarantee.
7.Changes in articles of incorporation or amendments to charter:Explain the nature and purpose of such changes or amendments.
8.State the estimated annual effect and nature of any important wage scale changes during the year.
9.State briefly the status of any materially important legal proceedings pending at the end of the year,and the results of any such
proceedings culminated during the year.
10.Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer,
director,security holder reported on Page 106,voting trustee,associated company or known associate of any of these persons was a
party or in which any such person had a material interest.
11.(Reserved.)
12.If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are
applicable in every respect and furnish the data required by Instructions 1 to 11 above,such notes may be included on this page.
PAGE 108 INTENTIONALLY LEFT BLANK
SEE PAGE 109 FOR REQUIRED INFORMATION.
FERC FORM NO.1 (ED.12-96)Page 108
Name of Respondent This Report is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000IMPORTANTCHANGESDURINGTHEYEAR(Continued)
1.None
2 .None
3 .None
4 .None
5.As of December 31,2000 Idaho Power Company transferred ownership of a 230KvtransmissionlinetoAvistaCorporation.The line runs from Imnaha to Divide CreekinWallowaCounty,Oregon and is licensed under FERC Project No.1971.The transferwasauthorizedbyFERCDocketNo.EC01-32-000.
6.$80 million of 7.38%First Mortgage Bonds maturing 12/1/07 were issued 12/1/00OPUCOrder#2005-E5-93-13 IPUC Order IPC-E-00-15 dated 12/31/00,and NPS OrderUF-4111.
7 .None
8.On December 29,2000,a general wage increase of 3.1%
9 .None
10 .None
FERC FORM NO.1 (ED.12-96)Page 109
Name of Respondent This Report Is:Date of Report Year of Report
Idaho Power Company (1)An Original (Mo,Da,Yr)
(2)A Resubmission 04/30/2001 Dec.31,2000
COMPARATIVE BALANCE SHEET (ASSETE AND OTHEF DEBITS)
Ref.Balance at Balance atLineTitleofAccount
No.(a)Page No.Beginning of Year End of Year
(b)(c)(d)
1 UTILITY PLANT yp
2 Utility Plant (101-106,114)200-201 2,727,768,439 2,802,041,757
3 Construction Work in Progress (107)200-201 86,634,047 131,238,324
4 TOTAL Utility Plant (Enter Total of lines 2 and 3)2,814,402,486 2,933,280,081
5 (Less)Accum.Prov.for Depr.Amort.Depl.(108,111,115)200-201 1,073,722,433 1,142,572,365
6 Net Utility Plant (Enter Total of line 4 less 5)1,740,680,053 1,790,707,716
7 Nuclear Fuel (120.1-120.4,120.6)202-203 0 0
8 (Less)Accum.Prov.for Amort.of Nucl.Fuel Assemblies (120.5)202-203 0 0
9 Net Nuclear Fuel (Enter Total of line 7 less 8)0 0
10 Net Utility Plant(Enter Total of lines 6 and 9)1,740,680,053 1,790,707,716
11 Utility PlantAdjustments (116)122 0 0
12 Gas Stored Underground -Noncurrent (117)0 0
13 OTHER PROPERTY AND INVESTMENTS
14 Nonutility Property (121)221 1,252,609 1,101,872
15 (Less)Accum.Prov.for Depr.and Amort.(122)0 0
16 Investments in Associated Companies (123)0 0
17 Investment in Subsidiary Companies (123.1)224-225 36,678,880 14,342,086
18 (For Cost of Account 123.1,See Footnote Page 224,line 42)
19 Noncurrent Portion of Allowances 228-229 0 0
20 Other Investments (124)335,539 181,618
21 Special Funds (125-128)471,065 307
22 TOTAL Other Property and Investments (Total of lines 14-17,19-21)38,738,093 15,625,883
23 CURRENT AND ACCRUED ASSETS
24 Cash (131)1,140,170 80,677,074
25 Special Deposits (132-134)1,240 1,240
26 Working Fund (135)42,517 41,217
27 Temporary Cash Investments (136)89,112,743 2,726,600
28 Notes Receivable (141)4,449,994 7,687,362
29 Customer Accounts Receivable (142)112,507,586 1,787,976,964
30 Other Accounts Receivable (143)3,703,241 4,885,010
31 (Less)Accum.Prov.for Uncollectible Acct.-Credit (144)1,397,454 1,397,454
32 Notes Receivable from Associated Companies (145)0 0
33 Accounts Receivable from Assoc.Companies (146)206,246 310,803
34 Fuel Stock (151)227 9,328,580 5,104,792
35 Fuel Stock Expenses Undistributed (152)227 746 86
36 Residuals (Elec)and Extracted Products (153)227 0 0
37 Plant Materials and Operating Supplies (154)227 22,274,579 21,722,827
38 Merchandise (155)227 0 0
39 Other Materials and Supplies (156)227 0 0
40 Nuclear Materials Held for Sale (157)202-203/227 0 0
41 Allowances (158.1 and 158.2)228-229 0 0
42 (Less)Noncurrent Portion of Allowances 0 0
43 Stores Expense Undistributed (163)227 3,729,950 2,961,551
44 Gas Stored Underground -Current (164.1)0 0
45 Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)0 0
46 Prepayments (165)16,115,601 24,144,262
47 Advances for Gas (166-167)0 0
48 interest and Dividends Receivable (171)490,115 54,651
49 Rents Receivable (172)0 0
50 Accrued Utility Revenues (173)31,994,447 44,824,990
51 Miscellaneous Current and Accrued Assets (174)0 0
52 TOTAL Current and Accrued Assets (Enter Total of lines 24 thru 51)293,700,301 1,981,721,975
FERC FORM NO.1 (ED.12-94)Page 110
Name of Respondent This Report Is:Date of Report Year of Report
Idaho Power Company (1)O An Original (Mo,Da,Yr)
(2)[¯]A Resubmission 04/30/2001 Dec.31,2000
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBlTS)Continued)
Ref.'Balance at Balance atLineTitleofAccountPageNo.Beginningof Year End of Year |No.(a)(b)(c)(d)I
53 DEFERRED DEBITS
54 Unamortized Debt Expenses (181)6,964,237 7,191,471
55 Extraordinary Property Losses (182.1)230 0 0
56 Unrecovered Plant and Regulatory Study Costs (182.2)230 0 0
57 Other Regulatory Assets (182.3)232 268,434,200 379,206,579
58 Prelim.Survey and Investigation Charges (Electric)(183)0 0
59 Prelim.Sur.and invest.Charges (Gas)(183.1,183.2)0 0
60 Clearing Accounts (184)0 0
61 Temporary Facilities (185)-171,415 -171,415
62 Miscellaneous Deferred Debits (186)233 110,193,097 108,144,889
63 Def.Losses from Disposition of Utility Pit.(187)0 0
64 Research,Devel.and Demonstration Expend.(188)352-353 0 0
65 Unamortized Loss on Reaquired Debt (189)7,529,029 6,384,225
66 Accumulated Deferred income Taxes (190)234 61,863,796 71,671,795
67 Unrecovered Purchased Gas Costs (191)0 0
68 TOTAL Deferred Debits (Enter Total of lines 54 thru 67)454,812,944 572,427,544
69 TOTAL Assets and Other Debits (Enter Total of lines 10,11,12,22,52,68)2,527,931,391 4,360,483,118
FERC FORM NO.1 (ED.12-94)Page 111
Name of Respondent This Report Is:Date of Report Year of Report
Idaho Power Company (1)An Original (Mo,Da,Yr)
(2)A Resubmission 04/30/2001 Dec.31,2000
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Ref.Balance at Balance atLineTitleofAccount
No.(a)Page No.Beginning of Year End of Year
(b)(c)(d)
1 PROPRIETARY CAPITAL
2 Common Stock Issued (201)250-251 94,030,878 94,030,878
3 Preferred Stock Issued (204)250-251 105,811,200 105,065,600
4 Capital Stock Subscribed (202,205)252 0 0
5 Stock Liability for Conversion (203,206)252 0 0
6 Premium on Capital Stock (207)252 361,856,126 361,846,434
7 Other Paid-In Capital (208-211)253 346,954 583,196
8 Installments Received on Capital Stock (212)252 0 0
9 (Less)Discount on Capital Stock (213)254 0 0
10 (Less)Capital Stock Expense (214)254 3,818,922 4,023,516
11 Retained Earnings (215,215.1,216)118-119 255,262,485 302,767,160
12 Unappropriated Undistributed Subsidiary Earnings (216.1)118-119 20,452,430 10,111,802
13 (Less)Reaquired Capital Stock (217)250-251 0 0
14 TOTAL Proprietary Capital (Enter Total of lines 2 thru 13)833,941,151 870,381,554
15 LONG-TERM DEBT GÑ$Ñ
16 Bonds (221)256-257 807,460,000 807,460,000
17 (Less)Reaquired Bonds (222)256-257 0 0
18 Advances from Associated Companies (223)256-257 0 0
19 Other Long-Term Debt (224)256-257 32,999,903 32,924,141
20 Unamortized Premium on Long-Term Debt (225)0 0
21 (Less)Unamortized Discount on Long-Term Debt-Debit (226)1,441,499 1,330,085
22 TOTAL Long-Term Debt (Enter Total of lines 16 thru 21)839,018,404 839,054,056
23 OTHER NONCURRENT LIABILITIES Ñ ijQ
24 Obligations Under Capital Leases -Noncurrent (227)0 0
25 Accumulated Provision for Property Insurance (228.1)O 0
26 Accumulated Provision for injuries and Damages (228.2)1,500,000 1,500,000
27 Accumulated Provision for Pensions and Benefits (228.3)2,553,978 2,333,829
28 Accumulated Miscellaneous Operating Provisions (228.4)4,593,805 2,072,506
29 Accumulated Provision for Rate Refunds (229)8,892,770 0
30 TOTAL OTHER Noncurrent Liabilities (Enter Total of lines 24 thru 29)17,540,553 5,906,335
31 CURRENT AND ACCRUED LIABILITIES
32 Notes Payable (231)19,000,000 59,700,000
33 Accounts Payable (232)118,374,474 1,840,582,896
34 Notes Payable to Associated Companies (233)2,579,220 5,166,082
35 Accounts Payable to Associated Companies (234)5,932,402 4,211,503
36 Customer Deposits (235)212,500 58,935
37 Taxes Accrued (236)262-263 14,976,322 6,183,217
38 Interest Accrued (237)17,066,178 14,777,890
39 Dividends Declared (238)153,397 316,250
40 Matured Long-Term Debt (239)0 0
41 Matured Interest (240)0 0
42 Tax Collections Payable (241)8,279 1,055,244
43 Miscellaneous Current and Accrued Liabilities (242)15,702,855 18,691,491
44 Obligations Under Capital Leases-Current (243)O 0
45 TOTAL Current &Accrued Liabilities (Enter Total of lines 32 thru 44)194,005,627 1,950,743,508
FERC FORM NO.1 (ED.12-89)Page 112
Name of Respondent This Report Is:Date of Report Year of Report
Idaho Power Company (1)An Original (Mo,Da,Yr)
(2)A Resubmission 04/30/2001 Dec.31,2000
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)(Continued)
Ref.Balance at Balance atLineTitleofAccountPageNo.Beginning of Year End of YearNo.(a)
(b)(c)(d)46 DEFERRED CREDITS g,47 Customer Advances for Construction (252)14,368,570 13,668,49648AccumulatedDeferredInvestmentTaxCredits(255)266-267 67,433,272 66,049,87849DeferredGainsfromDispositionofUtilityPlant(256)0 050OtherDeferredCredits(253)269 40,906,811 41,509,95051OtherRegulatoryLiabilities(254)278 37,179,794 44,850,93052UnamortizedGainonReaquiredDebt(257)0 053AccumulatedDeferredIncomeTaxes(281-283)272-277 483,537,209 528,318,41154TOTALDeferredCredits(Enter Total of fines 47 thru 53)643,425,656 694,397,665550056005700580059006000610062006300640065
0|06600670068TOTALLiabandOtherCredits(Enter Total of lines 14,22,30,45,54)2,527,931,391 4,360,483,118
FERC FORM NO.1 (ED.12-89)Page 113
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
STATEMENT OF INCOME FOR THE YEAR
1.Report amounts for accounts 412 and 413,Revenue and Expenses from Utility Plant Leased to Others,in another Utility column (i,
k,m,o)in a similar manner to a utility department.Spread the amount(s)over Lines 02 thru 24 as appropriate.Include these amounts
in columns (c)and (d)totals.
2.Report amounts in account 414,Other Utility Operating income,in the same manner as accounts 412 and 413 above.
3.Report data for lines 7,9,and 10 for Natural Gas companies using accounts 404.1,404.2,404.3,407.1 and 407.2.
4.Use pages 122-123 for important notes regarding the statement of income or any account thereof.
5.Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount
may need to be made to the utility's customers or which may result in a material refund to the utility with respect to power or gas
purchases.State for each year affected the gross revenues or costs to which the contingency relates and the tax effects together with
an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to
power and gas purchases.
6.Give concise explanations concerning significant amounts of any refunds made or received during the year
Line Account |(Ref.)TOTAL
No Page No.Current Year Previous Year
(a)(b)(c)(d)
1 UTILITY OPERATING INCOME REXW
2 Operating Revenues (400)300-301 835,661 764 658,336,167
3 Operating Expenses .ggg
4 Operation Expenses (401)320-323 518,598,906 344,258,867
5 Maintenance Expenses (402)320-323 46,973,047 42,067,673
6 Depreciation Expense (403)336-337 76,404,461 74,559,530
7 Amort.&Depl.of Utility Plant (404-405)336-337 3,966,055 3,355,671
8 Amort.of Utility PlantAcq.Adj.(406)336-337 -22,723 -22,723
9 Amort.Property Losses,Unrecov Plant and Regulatory Study Costs (407)
10 Amort.of Conversion Expenses (407)
11 Regulatory Debits (407.3)
12 (Less)Regulatory Credits (407.4)
13 Taxes Other Than IncomeTaxes (408.1)262-263 20,166,336 21,718,896
14 Income Taxes -Federal (409.1)262-263 -10,776,914 42,724,027
15 -Other (409.1)262-263 -3,819,821 8,648,173
16 Provision for Deferred Income Taxes (410.1)234,272-277 65,677,460 18,273,697
17 (Less)Provision for Deferred Income Taxes-Cr.(411.1)234,272-277 13,990,404 21,575,718
18 investment Tax Credit Adj.-Net (411.4)266 -1,383,394 -1,962,451
19 (Less)Gains from Disp.of Utility Plant (411.6)-2,162
20 Losses from Disp.of Utility Plant (411.7)12,328 12,328
21 (Less)Gains from Disposition of Allowances (411.8)75,134 72,132
22 Losses from Disposition of Allowances (411.9)
23 TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 22)701,732,365 531,985,838
24 Net Util Oper Inc (Enter Tot line 2 less 23)Carry fwd to P117,line 25 133,929,399 126,350,329
FERC FORM NO.1 (ED.12-96)Page 114
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
STATEMENT OF INCOME FOR THE YEAR (Continued)
resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases,and asummaryoftheadjustmentsmadetobalancesheet,income,and expense accounts.
7.If any notes appearing in the report to stockholders are applicable to this Statement of Income,such notes may be included onpages122-123.
B.Enter on pages 122-123 a concise explanation of only those changes in accounting methods made during the year which had aneffectonnetincome,including the basis of allocations and apportionments from those used in the preceding year.Also give theapproximatedollareffectofsuchchanges.
9.Explain in a footnote if the previous year's figures are different from that reported in prior reports.
10.If the columns are insufficient for reporting additional utility departments,supply the appropriate account titles,lines 2 to 23,andreporttheinformationintheblankspaceonpages.122-123 or in a footnote.
ELECTRIC UTILITY GAS UTILITY OTHER UTILITY Line
Current Year Previous Year Current Year Previous Year Current Year Previous Year(e)(f)(g)(h)(i)(j)
835,661,764 658,336,167 2
518,598,906 344,258,867 4
46,973,047 42,067,673 5
76,404,461 74,559,530 6
3,966,055 3,355,671 7
-22,723 -22,723 8
9
10
11
12
20,166,336 21,718,896 13
-10,776,914 42,724,027 14
-3,819,821 8,648,173 15
65,677,460 18,273,697 16
13,990,404 21,575,718 17
-1,383,394 -1,962,451 18
-2,162 19
12,328 12,328 20
75,134 72,132 21
22
701,732,365 531,985,838 23
133,929,399 126,350,329 24
FERC FORM NO.1 (ED.12-96)Page 115
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
3TATEMENT OF INCOME FOR THE YEAR (Contin red)
Line Account (Ref.)TOTAL
No.Page No.Current Year Previous Year
(a)(b)(c)(d)
25 Net Utility Operating Income (Carried forward from page 114)133,929,399 126,350,329
26 Other Income and Deductions
27 Other Income
28 Nonutilty Operating Income
29 Revenues From Merchandising,Jobbing and Contract Work (415)1,343,844 1,822,835
30 (Less)Costs and Exp.of Merchandising,Job.&Contract Work (416)1,472,984 2,169,380
31 Revenues From Nonutility Operations (417)125,232
32 (Less)Expenses of Nonutility Operations (417.1)3,809 411,488
33 Nonoperating Rental income (418)-20,628 -25,634
34 Equity in Earnings of Subsidiary Companies (418.1)119 8,357,882 8,931,659
35 Interest and Dividend income (419)2,669,627 2,785,186
36 Allowance for Other Funds Used During Construction (419.1)2,565,391 1,667,021
37 Miscellaneous Nonoperating Income (421)94,341,820 23,988,960
38 Gain on Disposition of Property (421.1)40,556 702,105
39 TOTAL Other Income (Enter Total of lines 29 thru 38)107,821,699 37,416,496
40 Other income Deductions J.
41 Loss on Disposition of Property (421.2)2,201 6,365
42 Miscellaneous Amortization (425)340
43 Miscellaneous Income Deductions (426.1-426.5)340 3,068,251 470,417
44 TOTAL Other Income Deductions (Total of lines 41 thru 43)3,070,452 476,782|
45 Taxes Applic.to Other Income and Deductions
46 Taxes Other Than Income Taxes (408.2)262-263 24,088 21,411
47 Income Taxes-Federal (409.2)262-263 44,461,822 5,971,434
48 Income Taxes-Other (409.2)262-263 9,216,737 1,225,191
49 Provision for Deferred inc.Taxes (410.2)234,272-277 2,936,842 1,520,157
50 (Less)Provision for Deferred income Ta×es-Cr.(411.2)234,272-277 11,246,789 -345,675
51 Investment Ta× Credit Adj.-Net (411.5)
52 (Less)Investment Tax Credits (420)
53 TOTAL Taxes on Other income and Deduct.(Total of 46 thru 52)45,392,700 9,083,868
54 Net Other Income and Deductions (Enter Total lines 39,44,53)59,358,547 27,855,846
55 Interest Charges
56 Interest on Long-Term Debt (427)53,253,094 54,149,881
57 Amort.of Debt Disc.and Expense (428)970,519 969,872
58 Amortization of Loss on Reaquired Debt (428.1)744,807 1,121,080
59 (Less)Amort,of Premium on Debt-Credit (429)
60 (Less)Amortization of Gain on Reaquired Debt-Credit (429.1)
61 Interest on Debt to Assoc.Companies (430)340 349,652 171,234
62 Other Interest Expense (431)340 2,828,265 1,658,058
63 (Less)Allowance for Borrowed Funds Used During Construction-Cr.(432)2,346,355 1,391,624
64 Net Interest Charges (Enter Total of lines 56 thru 63)55,799,982 56,678,501
65 Income Before Extraordinary Items (Total of lines 25,54 and 64)137,487,964 97,527,674
66 Extraordinary Items
67 Extraordinary Income (434)
68 (Less)Extraordinary Deductions (435)
69 Net Extraordinary Items (Enter Total of line 67 less line 68)
7 Income Taxes-Federal and Other (409.3)262-263
71 Extraordinary Items After Taxes (Enter Total of line 69 less line 70)
7 Net income (Enter Total of lines 65 and 71)137,487,964 97,527,674
FERC FORM NO.1 (ED.12-96)Page 117
This Page Intentionally Left Blank
l Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
STATEMENT OF RETAINED EARNINGS FORTHE YEAR
1.Report all changes in appropriated retained earnings,unappropriated retained earnings,and unappropriated undistributed
subsidiary earnings for the year.
2.Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433,436
-439 inclusive).Show the contra primary account affected in column (b)
3.State the purpose and amount of each reservation or appropriation of retained earnings.
4.List first account 439,Adjustments to Retained Earnings,reflecting adjustments to the opening balance of retained earnings.Follow
by credit,then debit items in that order.
5.Show dividends for each class and series of capital stock.
6.Show separately the State and Federal income tax effect of items shown in account 439,Adjustments to Retained Earnings.
7.Explain in a footnote the basis for determining the amount reserved or appropriated.If such reservation or appropriation is to be
recurrent,state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated.
8.If any notes appearing in the report to stockholders are applicable to this statement,include them on pages 122-123.
Line Contra Arimary Amount
No.Item Account Affected(a)(b)(c)
UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1 Balance-Beginning of Year 253,718 519
2 Changes
3 Adjustments to Retained Earnings (Account 439)
4
5
6
7
8
9 TOTAL Credits to Retained Earnings (Acct.439)
10
11
12
13
14
15 TOTAL Debits to Retained Earnings (Acct.439)
16 Balance Transferred from income (Account 433 less Account 418.1)129,130,082
17 Appropriations of Retained Earnings (Acct.436)
18
19
20
21
22 TOTAL Appropriations of Retained Earnings (Acct.436)
23 Dividends Declared-Preferred Stock (Account 437)
24 4%Preferred (par value $100)238 -622,904
25 7.68%Serial preferred (par value $100)238 -1,152,000
26 Auction Rate Preferred,series A (stated value $100,000)238 -2,386,573
27 7.07%Serial Preferred (par value $100,000)238 -1,767,500
28
29 TOTAL Dividends Declared-Preferred Stock (Acct.437)-5,928,977
30 Dividends Declared-Common Stock (Account 438)
31 $2.50 Par Value -69,850,035
32
33
34
35
36 TOTAL Dividends Declared-Common Stock (Acct.438)-69,850,035
37 Transfers from Acct 216.1,Unapprop.Undistrib.Subsidiary Earnings -5,846,395
38 Balance -End of Year (Total 1,9,15,16,22,29,36,37)301,223,194
APPROPRIATED RETAINED EARNINGS (Account 215)
FERC FORM NO.1 (ED.12-96)Page 118
Name of Respondent This Report is:Date of Report Year of Report(1)g An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
STATEMENT OF RETAINED EARNINGS FOR THE YEAR
1.Report all changes in appropriated retained earnings,unappropriated retained earnings,and unappropriated undistributedsubsidiaryearningsfortheyear.
2.Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433,436-439 inclusive).Show the contra primary account affected in column (b)3.State the purpose and amount of each reservation or appropriation of retained earnings.4.List first account 439,Adjustments to Retained Earnings,reflecting adjustments to the opening balance of retained earnings.Followbycredit,then debit items in that order.
5.Show dividends for each class and series of capital stock.
6.Show separately the State and Federal income tax effect of items shown in account 439,Adjustments to Retained Earnings.7.Explain in a footnote the basis for determining the amount reserved or appropriated.If such reservation or appropriation is to berecurrent,state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated.8.If any notes appearing in the report to stockholders are applicable to this statement,include them on pages 122-123.
Line Õontra Primary AmountNo.Item Account Affected(a)(b)(c)39
40
41
42
43
44
45 TOTAL Appropriated Retained Earnings (Account 215)
APPROP.RETAINED EARNINGS -AMORT.Reserve,Federal (Account 215.1)
46 TOTAL Approp.Retained Earnings-Amort.Reserve,Federal (Acct.215.1)1,543,96647TOTALApprop.Retained Earnings (Acct.215,215.1)(Total 45,46)1,543,96648TOTALRetainedEarnings(Account 215,215.1,216)(Total 38,47)302,767,160UNAPPROPRIATEDUNDISTRIBUTEDSUBSIDIARYEARNINGS(Account 216.1)
49 Balance-Beginningof Year (Debit or Credit)20,452,43150EquityinEarningsforYear(Credit)(Account 418.1)8,357,88251(Less)Dividends Received (Debit)16,041,03152BridgerCoalReclamationTrust-2,657,48053Balance-End of Year (Total lines 49 thru 52)10,111,802
FERC FORM NO.1 (ED.12-96)Page 119
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
STATEMENT OF CASH FLOWS
1.If the notes to the cash flow statement in the respondents annual stockholders report are applicable to this statement,such notes should be included
in page 122-123.Information about non-cash investing and financing activities should be provided on Page 122-123.Provide also on pages 122-123 a
reconciliation between "Cash and Cash Equivalents at End of Year"with related amounts on the balance sheet.
2.Under "Other"specify significant amounts and group others.
3.Operating Activities -Other:Include gains and losses pertaining to operating activities only.Gains and losses pertaining to investing and financing
activities should be reported in those activities.Show on Page 122-123 the amount of interest paid (net of amounts capitalized)and income taxes paid.
Line Description (Šee Instruction Ño.5 for Êxplanation of Óodes)Amounts
No.(a)(b)
1 Net Cash Flow from Operating Activities:
2 Net Income 137,487,964
3 Noncash Charges (Credits)to Income:
4 Depreciation and Depletion 79,177,296
5 Amortization of electric plant -limited term and acquistion adj 3,943,332
6
7
8 Deferred Income Taxes (Net)43,377,107
9 InvestmentTax Credit Adjustment (Net)-1,383,394
10 Net (Increase)Decrease in Receivables -144,062,999
11 Net (Increase)Decrease in Inventory 5,544,600
12 Net (Increase)Decrease in Allowances Inventory
13 Net Increase (Decrease)in Payables and Accrued Expenses 148,081,114
14 Net (Increase)Decrease in Other Regulatory Assets -114,380,297
15 Net Increase (Decrease)in Other Regulatory Liabilities 1,258,078
16 (Less)Allowance for Other Funds Used During Construction -2,565,391
17 (Less)Undistributed Earnings from Subsidiary Companies 2,357,881
18 Other:
19 Unbilled -12,830,543
20 Unrealized gain (loss)on energy trading 21,846,636
21 Other Amort and Other-Net -776,800
22 Net Cash Provided by (Used in)Operating Activities (Total 2 thru 21)167,489,604
23
24 Cash Flows from Investment Activities:
25 Construction and Acquisition of Plant (including land):
26 Gross Additions to Utility Plant (less nuclear fuel)-138,030,031
27 Gross Additions to Nuclear Fuel
28 Gross Additions to Common Utility Plant
29 Gross Additions to Nonutility Plant
30 (Less)Allowance for Other Funds Used During Construction 2,565,391
31 Other:
32 Acquisition o other non-current assets 186,419
33 Investments in and advances to assoc companies -53,299
34 Cash Outflows for Plant (Total of lines 26 thru 33)-140,462,302
36 Acquisition of Other Noncurrent Assets (d)
37 Proceeds from Disposal of Noncurrent Assets (d)
38
39 Investments in and Advances to Assoc.and Subsidiary Companies
40 Contributions and Advances from Assoc.and Subsidiary Companies
42 Associated and Subsidiary Companies
43
44 Purchase of Investment Securities (a)
45 Proceeds from Sales of Investment Securities (a)
FERC FORM NO.1 (ED.12-96)Page 120
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubm¡ssion 04/30/2001 Dec.31,
STATEMENT OF CASH FLOWS
4.Investing Activities include at Other (line 31)net cash outflow to acquire other companies.Provide a reconciliation of assets acquired with liabilitiesassumedonpages122-123.Do not include on this statement the dollar amount of Leases capitalized per US of A General Instruction 20,insteadprovideareconciliationofthedollaramountofLeasescapitalizedwiththeplantcostonpages122-123.
5.Codes used:
(a)Net proceeds or payments.(c)Include commercial paper.
(b)Bonds,debentures and other long-term debt.(d)Identify separately such items as investments,fixed assets,intangibles,etc.6.Enter on pages 122-123 clarifications and explanations.
Line Description (See instruction No.5 for Ëxplanation of Codes)AmountsNo.(a)(b)46 Loans Made or Purchased
47 Collections on Loans
48
49 Net (increase)Decrease in Receivables
50 Net (Increase )Decrease in Inventory
51 Net (Increase)Decrease in Allowances Held for Speculation
52 Net Increase (Decrease)in Payables and Accrued Expenses
53 Other
54
55
56 Net Cash Provided by (Used in)Investing Activities
Total of linesfr34thFna5n5cing
Activities:
60 Proceeds from issuance of:
61 Long-Term Debt (b)84,360,00062PreferredStock
63 Common Stock
64 Other:
65 issuance costs -919,73866NetIncreaseinShort-Term Debt (c)
67 Other:
68
69
70 Cash Provided by Outside Sources (Total 61 thru 69)83,440,26271
72 Payments for Retirement of:
73 Long-term Debt (b)-84,360,00074PreferredStock-501,60475CommonStock
76 Other:35,65177
78 Net Decrease in Short-Term Debt (c)43,286,86279
80 Dividends on Preferred Stock -5,928,97781DividendsonCommonStock-69,850,035
83 (Total of lines 70 thru 81)-33,877,84184
86 (Total of lines 22,57 and 83)-6,850,53987
88 Cash and Cash Equivalents at Beginning of Year 90,295,430
90 Cash and Cash Equivalents at End of Year 83,444,891
FERC FORM NO.1 (ED.12-96)Page 121
Name of Respondent This Report Is:Date of Report Year of Report
Idaho Power Company (1)An Original 04/30/2001 Dec.31,2000
(2)A Resubmission
NOTES TO FINANCIAL STATEMENTS
1.Use the space below for important notes regarding the Balance Sheet,Statement of Income for the year,Statement of Retained
Earnings for the year,and Statement of Cash Flows,or any account thereof.Classify the notes according to each basic statement,
providing a subheading for each statement except where a note is applicable to more than one statement.
2.Furnish particulars (details)as to any significant contingent assets or liabilities existing at end of year,including a brief explanation of
any action initiated by the Internal Revenue Service involvingpossible assessment of additional income taxes of material amount,or of
a claim for refund of income taxes of a material amount initiated by the utility.Give also a brief explanation of any dividends in arrears
on cumulative preferred stock.
3.For Account 116,Utility Plant Adjustments,explain the origin of such amount,debits and credits during the year,and plan of
disposition contemplated,giving references to Cormmission orders or other authorizations respecting classification of amounts as plant
adjustments and requirements as to disposition thereof.
4.Where Accounts 189,Unamortized Loss on Reacquired Debt,and 257,Unamortized Gain on Reacquired Debt,are not used,give
an explanation,providing the rate treatment given these items.See General Instruction 17 of the Uniform System of Accounts.
5.Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such
restrictions.
6.If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are
applicable and furnish the data required by instructions above and on pages 114-121,such notes may be included herein.
PAGE 122 INTENTIONALLY LEFT BLANK
SEE PAGE 123 FOR REQUIRED INFORMATION.
FERC FORM NO.1 (ED.12-96)Page 122
Idaho Power Company An Original December 31,2000
Idaho Power Company
Notes to the Consolidated Financial Statements
On October 1,1998,IDACORP,Inc.(IDACORP)became the parent of Idaho Power Company andsubsidiaries(IPC or the Company).At that time ownership interests in two of IPC's subsidiaries weretransferredtoIDACORPatbookvalue.IPC's financial statements include $3.0 million of net incomeattributabletothetransferredsubsidiariesfortheyearendedDecember31,1998.
On January 1,2000 IPC's ownership interests in two additional subsidiaries were transferred to IDACORP atbookvalue.IPC's financial statements include the following amounts attributable to these transferredsubsidiariesfortheperiodspriortoJanuary1,2000:
As of/Year Ended December 31,
1999 1998
Total assets........................................$107,996 $90,029Netassets...............................22,090 19,706Netincome.................................2,385 2,216
Basis of Presentation
These financial statements were prepared in accordancewith the accounting requirements of the FederalEnergyRegulatoryCommission(FERC)as set forth in its applicable Uniform System of Accounts andpublishedaccountingreleases,which is a comprehensive basis of accounting other than generally acceptedaccountingprinciples.
Utility Plant
The cost of additions to utility plant in service represents the original cost of contracted services,direct laborandmaterial,allowance for funds used during construction and indirect charges for engineering,supervisionandsimilaroverheaditems.Maintenance and repairs of property and replacementsand renewals of itemsdeterminedtobelessthanunitsofpropertyarechargedtooperations.For property replacedor renewed theoriginalcostplusremovalcostlesssalvageischargedtoaccumulatedprovisionfordepreciationwhilethecostofrelatedreplacementsandrenewalsisaddedtoutilityplant.
AIIowance for Funds Used During Construction (AFDC)
The allowance,a non-cash item,representsthe composite interest costs of debt,shown as a reduction tointerestcharges,and a return on equity funds,shown as an addition to other income,used to financeconstruction.While cash is not realized currently from such allowance,it is realized underthe rate makingprocessovertheservicelifeoftherelatedpropertythroughincreasedrevenuesresultingfromhigherratebaseandhigherdepreciationexpense.Based on the uniform formula adopted by the FERC,IPC's weighted-averagemonthly AFDC rates for 2000 and 1999 were 8.3 percent and 7.8 percent respectively.
Revenues
In order to match revenues with associated expenses,IPC accrues unbilled revenues for electric servicesdeliveredtocustomersbutnotyetbilledatmonth-end.
IPC had a regulatory settlement with the Idaho Public Utilities Commission (IPUC)that expired in 1999.Under terms of the settlement,when earnings in the Idahojurisdiction exceeded an I1.75 percent return on
123
Idaho Power Company An Original December 31,2000
year-end common equity,50 percent of the excess was set aside for the benefit of IPC's Idaho retail customers.
In March 2000 IPC submitted a 1999 annual earnings sharing compliance filing to the IPUC.This filing
indicated that there was almost $9.6 million in 1999 earnings and $2.7 million in unused 1998 reserve balances
available for the benefit of IPC's Idaho customers.In April 2000 the IPUC ordered that $6.9 million of the
revenue sharing balancebe refunded to Idaho customers through rate reductions effective May 16,2000.The
IPUC also approved IPC's continuing participation in the Northwest Energy Efficiency Alliance (NEEA)
through 2004,ordering IPC to set aside the remaining $5.4 million of revenue sharing dollars to fund that
participation.
Power Cost Adjustment
IPC has a Power Cost Adjustment (PCA)mechanismthat provides for annual adjustments to the rates charged
to Idaho retail customers.These adjustments are based on forecasts of net power supply costs,and take effect
annually on May 16.The difference between the actual costs incurred and the forecasted costs are deferred,
with interest,and trued-up in future annual rate adjustments.
Depreciation
All utility plant in service is depreciated using the straight-line method at rates approved by regulatory
authorities.Annual depreciation provisions as a percent of averagedepreciable utility plant in service
approximated 2.94 percent in 2000 and 2.94 percent in 1999.
Income Taxes
The Company follows the liability method of computing deferred taxes on all temporary differences between
the book and tax basis of assets and liabilities and adjusts deferred tax assets and liabilities for enacted changes
in tax laws or rates.Consistent with orders and directives of the IPUC,the regulatory authority having
principaljurisdiction,IPC's deferred income taxes (commonly referred to as normalized accounting)are
provided for the difference between income tax depreciation and straight-line depreciation computed using
book lives on coal-fired generation facilities and properties acquired after 1980.On other facilities,deferred
income taxes are provided for the difference between acceleratedincome tax depreciation and straight-line
depreciation using tax guideline lives on assets acquired prior to 1981.Deferred income taxes are not provided
for those income tax timing differences where the prescribed regulatory accounting methodsdo not provide for
current recovery in rates.Regulated enterprisesare required to recognize such adjustments as regulatory assets
or liabilities if it is probable that such amounts will be recovered from or returned to customers in future rates.
The State of Idaho allows a three-percent investment tax credit (ITC)upon certain qualifying plant additions.
ITC earned on regulated assets are deferred and amortized to income over the estimated service lives of the
related properties.Credits earned on non-regulated assets or investments are recognized in the year earned.
Cash and Cash Equivalents
For purposesof reporting cash flows,cash and cash equivalents include cash on hand and highly liquid
temporary investments with maturity dates at date of acquisition of three months or less.
Management Estimates
The preparation of financial statements in conformity with accounting principles generally accepted in the
United States of America,requires managementto make estimates and assumptions that affect the reported
amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the
financial statements and the reported amounts of revenues and expenses during the reporting period.Actual
results could differ from those estimates.
123-1
Idaho Power Company An Original December 31,2000
Regulation of Utility Operations
Electric utilities havehistorically been recognized as natural monopolies and have operatedin a highlyregulatedenvironmentinwhichtheyhaveanobligationtoprovideelectricservicetotheircustomersin returnforanexclusivefranchisewithintheirserviceterritorywithanopportunitytoearnaregulatedrateofreturn.This regulatory environment is changing.The generation sector has experienced competition from non-utilitypowerandmarketproducers,and the FERC is requiring utilities,includingIPC,to provide wholesale open-access transmission service to others.Transmission services may soon be provided by Regional TransmissionOrganizationsratherthanutilities.
Some state regulatory authorities are in the process of changing utilityregulations in response to federal andstatestatutorychangesandevolvingcompetitivemarkets.These statutory and conforming regulations mayresultinincreasedwholesaleandretailcompetition.In 1997,the Idaho Legislature appointed a committee tostudyrestructuringoftheelectricutilityindustry.Although the committee will continue studying a variety ofrestructuringideas,it has not recommendedany restructuring legislation and is not expected to in theforeseeablefuture.In 1999,the Oregon legislature passed legislation restructuring the electric utilityindustry,but exemptedIPC's service territory.Due to IPC's low cost structure,it is well positioned to compete in theevolvingutilitymarketplace.However,the Company is unable to predict what financial impact or effect theadoptionofanysuchlegislationwouldhaveonIPC's operations.
IPC follows Statement of Financial Accounting Standards (SFAS)No.71,"Accountingfor the Effects ofCertainTypesofRegulation,"and its financial statements reflect the effects of the different rate makingprinciplesfollowedbythevariousjurisdictionsregulatingIPC.Pursuant to SFAS 71 IPC capitalizes,asdeferredregulatoryassets,incurred costs that are expected to be recovered in future utility rates.IPC alsorecordsasdeferredregulatoryliabilitiesthecurrentrecoveryinutilityratesofcoststhatareexpectedtobepaidinthefuture.
The following is a breakdown of IPC's regulatory assets and liabilities for the years 2000 and 1999:
2000 1999
Assets Liabilities Assets Liabilities
(Millions of Dollars)Income taxes.......................................$213.6 $40.2 $215.7 $33.8Conservation......................................32.3 -37.5 -Employee benefits ..............................3.7 -4.7 -
PCA deferral and amortization ...........119.9 -(3.4)Other.................................................9.7 4.7 13.9 3.4Deferredinvestmenttaxcredits..........-66.0 -67.4Total........................................$379.2 $110.9 $268.4 $104.6
At December31,2000,IPC had $5.5 million of regulatory assets that were not earning a return on investment,excluding the $213.6 million that relates to income taxes.
In the event that recovery of costs through rates becomes unlikelyor uncertain,SFAS 71 would no longerapply.If the Company were to discontinue application of SFAS 71 for some or all of IPC's operations,thentheseitemsmayrepresentstrandedinvestments.If the Company is not allowed recovery of these investments,it would be required to write off the applicable portion of regulatory assets and the financial effects could besignificant.
123-2
Idaho Power Company An Original December 31,2000
Derivative Financial Instruments
The Company uses financial instruments such as commodity futures,forwards,options and swaps to manage
exposure to commodity price risk in the electricity and natural gas markets.The objective of the Company's
risk managementprogram is to mitigate the risk associated with the purchaseand sale of natural gas and
electricity as well as to optimize its energy marketing portfolio.The accounting for derivative financial
instruments that are used to managerisk is in accordancewith the concepts establishedin SFAS No.80,
"Accounting for Futures Contracts,"American Institute of Certified Public Accountants Statement of Position
86-2,"Accounting for Options,"and Emerging Issues Task Force (EITF)98-10,"Accounting for Contracts
Involved in Energy Trading Activities".EITF 98-10 was adopted effective January 1,1999 resulting in an
adjustment to net income that was not material.
Energy trading contracts as defined by EITF 98-10 are reported at fair value on the balance sheet with the
resulting gains and losses reported on the income statement.The fair value of positions recordedon the
balance sheet is dependanton the prices and volatilityof the energy markets.As such,these items on the
balance sheet can fluctuate greatly without large changes in volumes or positions.Cash flows from energy
trading contracts are recognized in the statement of cash flows as an operating activity.
The following table shows a summary of the notional amounts of IPC's forward exposure (including both sales
and purchases)as of December 31,2000 and 1999.The maximum term related to any forward position is ten
years.
December 31,2000 December 31,1999
Electricity MWh's
Total gross notional volume .......................34,453 10,818
The following table displays the fair value of IPC's energy marketing assets and liabilities (all electricity)at
December 31,2000 and 1999 and the averagevalues for the twelve months ended December 31,2000 (in
thousands of dollars):
Balance at December 31,2000 Twelve Months Average Balance Balance at December 31,1999
Assets Liabilities Assets Liabilities Assets Liabilities
$1,572,619 $1,590,964 $401,956 $397,914 $29,096 $25,594
The gain in fair value of energy trading contract positions (including electricity forwards,futures,options and
swaps)included in the income before income taxes for the years ended December 31,2000 and 1999 were
$140.3 million and $29.7 million respectively.
Notional amounts listed above reflect the volume of energy related to transactions with counterparties,but do
not measure exposure to market or credit risks.The maximum term detailed above also is not indicative of
likely future cash flows as positions may be offset in the markets at any time to meet risk management
guidelines.
Comprehensive Income
Components of the Company's comprehensive income include net income,unrealized holding gains on
marketable securities,the Company's proportionate share of unrealized holding gains on marketable securities
held by an equity investee,and the changes in additional minimum liability under a deferred compensation
plan for certain senior managementemployees and directors.
123-3
Idaho Power Company An Original December 31,2000
New Accounting Pronouncements
In June 1998 the Financial Accounting Standards Board issued Statement of Financial Accounting StandardsNo.133 "Accounting for Derivative Instruments and Hedging Activities."In June 2000,the FASB issuedSFASNo.138 "Accounting for Certain Derivative Instruments and Certain Hedging Activities",whichamendedcertainprovisionsofSFAS133.The DerivativeImplementation Group,a task force created by theFASB,is continuing to identify and resolve implementation questionsrelated to SFAS 133 and SFAS 138.
SFAS 133,as amendedby SFAS 138,was effective as of January 1,2001.As of January 1,2001 contractscompany-wide have been evaluated based upon the SFAS 133 derivative definition and requirements.Most oftheCompany's identifiedderivatives consist of energy trading contracts that are currently reported at fair valueundertheprovisionsofEmergingIssuesTaskForce98-10.The remaining derivatives are IPC electricitypurchaseandsalescontractsthataresubjecttoregulatoryprocesses.As a result,the adoption of SFAS 133,asamended,did not have a material effect on the Company's financial position,results of operations,or cashflows.
Other Accounting Policies
Debt discount,expense and premium are being amortized over the terms of the respective debt issues.
Reclassifications
Certain items previously reported for years prior to 2000 have been reclassified to conform to the currentyear's presentation.
123-4
Idaho Power Company An Original December 31,2000
INCOME TAXES:
IPC has settled Federal and Idaho tax liabilities on all open years through the 1996 tax yearexcept for amounts
related to a partnership which have been,in management's opinion,adequately accrued.
A reconciliation between the statutory federal income tax rate and the effective rate and the effective rate for
the year 2000 and 1999 as follows:
2000 1999
(Thousands of Dollars)
Computed income taxes based on statutory
federal income tax rate ....................................$76,497 $53,444
Reduction in taxes resulting from:
Equity in earnings of subsidiary companies........$(2,925)$(3,126)
Investment tax credits restored............................(3,083)(3,032)
Repair allowance............................(4,550)(2,800)
Removal cost.....................................................(651)(710)
Elimination of amounts provided in prior years..0 (461)
Current state income taxes ..............................10,067 6,414 *
Depreciation...........................8,243 7,292
Other .....................................(2,522)(1,851)*
Total provision for income taxes.................................$81,076 $55,170
EffectiveTax Rate on Pretax Income..........................37.1%36.1%
*In 2000,$106 Reclassified from Other to Current State Income Taxes for the year 1999.
The provision for income taxes consists of the following:
2000 1999
(Thousands of Dollars)
Income taxes currently payable:
Federal.....................................$33,685 $48,696
State..............................5,397 9,873
Total........................................................39,082 58,569
Deferred taxes included in expenses -net:
Federal.....................................35,970 594
State ................................7,407 (2,030)
Total.................................43,377 (1,436)
Investment tax credits:
Deferred................................1,700 1,069
Restored................................(3,083)(3,032)
Total..........................................(1,383)(1,963)
Total provision for income taxes ........................$81,076 $55,170
The tax effects of significant items comprising the Company's net deferred tax liability are as follows:
2000 1999
(Thousands of Dollars)
Deferred tax liabilities:
Property,plant and equipment ........................$249,546 $249,597
Regulatory assets..................................213,552 215,675
Conservation programs ................................13,561 17,396
PCA.................................47,189 (1,826)
Other ................................4,471 2,695
Total........................................$528,319 $483,537
Deferred tax assets:
Regulatory liabilities .....................................$40,230 $33,817
Advances for construction...............................9,224 9,646
Other ...................................22,218 18,401
Total..........................................$71,672 $61,864
Net deferred tax liabilities...................................$456,647 $421,673
123-5
Idaho Power Company An Original December 31,2000
COMMON STOCK:
All common stock of IPC is owned by IDACORP.
PREFERREDSTOCK OF IDAHO POWER COMPANY:
The number of shares of IPC preferred stock outstanding at December 31,2000 and 1999 were as follows:
Shares Outstanding at
December 31,Call Price
2000 1999 Per SharePreferredstock:
Cumulative,$100 par value:
4%preferred stock (authorized
215,000 shares)..........................................150,656 158,112 $104.00Serialpreferredstock,7.68%Series
(authorized 150,000 shares)..................................150,000 150,000 $102.97Serialpreferredstock,cumulative,without
par value;total of 3,000,000 shares authorized:
7.07%Series,$100 stated value,(authorized 250,000 shares)(a).............................250,000 250,000 $103.535 to $100.354Auctionratepreferredstock,$100,000 stated
value,(authorized 500 shares)(b)..........................500 500 $100,000.00
Total..........................................551,156 558,612
(a)The preferred stock is not redeemable prior to July 1,2003.(b)Dividend rate at December 31,2000 was 4.95%and ranged between 4.28%and 5.00%during the year.
During 2000 and 1999 IPC reacquired and retired 7,456 shares and 1,568 shares of 4%preferred stock.As ofDecember31,2000,the overall effective cost of all outstanding preferred stock was 6.02 percent.
LONG-TERM DEBT:
On March 23,2000,IPC filed a $200.0 million shelf registration statement that can be used for first mortgagebonds(includingmedium term notes),unsecureddebt,or preferred stock.On December 1,2000,$80.0millionprincipalamountofSecuredMediumTermNotes,Series C,7.38%Series due 2007 were issued andproceedsfromthisissuancewereusedfortheearlyredemptioninJanuary2001ofthe$75.0 million FirstMortgageBonds9.50%,Series due 2021.At December31,2000,$120.0 million of the total remained to beissued.
The amount of first mortgagebonds issuable by IPC is limited to a maximum of $900.0 million and byproperty,earnings and other provisions of the mortgageand supplementalindentures thereto.Substantially alloftheelectricutilityplantissubjecttothelienoftheindenture.
Pollution Control RevenueBonds,Series 1984,due December 1,2014,are secured by First Mortgage Bonds,Pollution Control Series A,which were issued by IPC and are held by a Trustee for the benefit of thebondholders.
First mortgage bonds maturing during the five-year period ending 2005 are $30.0 million in 2001,$27.0millionin2002,$80.0 million in 2003,$50.0million in 2004 and $60.0 million in 2005.
On September9,1998,$60.0 million principal amount of Secured Medium Term Notes,Series B,5.83%Series due 2005 were issued by IPC.Proceeds from this issuance were used to redeem at maturity,the $30.0millionFirstMortgageBonds5.33%Series B due September 1998,with the balance used for repayment ofcommercialpaperissuedinconnectionwithIPC's ongoing business.
123-6
Idaho Power Company An Original December 31,2000
On November 23,1999,$80.0 million principal amount of SecuredMedium Term Notes,Series B,7.20%
Series due 2009 were issued by IPC.Proceeds from this issuance were used to redeemat maturity,the $80.0
million First Mortgage Bonds 8.65%Series due January2000.
On April 26,2000,at the request of IPC,the American Falls Reservoir District issued its American Falls
Refunding ReplacementDam Bonds,Series 2000,in the aggregateprincipal amount of $19.9 million for the
purpose of refunding on April 26,2000 a like amount of its bonds dated May 1,1990.IPC has guaranteed
repayment of these bonds.
On May 17,2000,tax exempt Pollution Control RevenueRefunding Bonds Series 2000 in the aggregate
principal amount of $4.4 million were issued by Port of Morrow,Oregon for the purpose of refunding on
August 1,2000,a like amount of its Pollution Control Revenue Bonds,Series 1978.
At December 31,2000 and 1999 the overall effective cost of all outstanding first mortgagebonds and pollution
control revenue bonds was 7.52 percent and 7.62 percent,respectively.
FAIR VALUE OF FINANCIAL INSTRUMENTS:
The estimatedfair value of the Company's financial instruments has been determined by the Companyusing
available market information and appropriate valuation methodologies.The use of different market
assumptions and/or estimation methodologies may have a material effect on the estimated fair value amounts.
Cash and cash equivalents,customer and other receivables,notes payable,accounts payable,interest accrued,
and taxes accrued are reported at their carrying value as these are a reasonable estimate of their fair value.The
estimated fair values for long-term debt and investments are based upon quoted market prices of the same or
similar issues or discounted cash flow analyses as appropriate.
The total estimated fair value of the Company's debt was approximately $866.3 million in 2000 and $898.1
million in 1999.
NOTES PAYABLE:
At December 31,2000,IPC had regulatory authority to incur up to $200 million of short-term indebtedness.
IPC has a $120 million multi-year revolvingcredit facility expiring in December 2001.Under this facility IPC
pays a facility fee on the commitment,quarterly in arrears,based on IPC's First Mortgage Bond rating.
Commercial paper may be issued subject to the regulatory maximum,and is supported by bank lines of credit
of an equal amount.
Balances and interest rates of short-term borrowings for IPC were as follows:
Year Ended December 31,
2000 1999
(Thousands of Dollars)
Balance at end of year...........................................$59,700 $19,757
Effective annual interest rate at end of year..........................6.8%6.1%
COMMITMENTS AND CONTINGENT LIABILITIES:
Commitments under contracts and purchase orders relating to IPC's program for construction and operation of
facilities amountedto approximately $8.3 million at December 31,2000.The commitments are generally
revocable,subject to reimbursement of manufacturers'expenditures incurred and/or other termination charges.
123-7
Idaho Power Company An Original December 31,2000
IPC is currently purchasing energy from 66 on-line cogeneration and small power production facilities withcontractsrangingfrom1to30years.Under these contracts IPC is required to purchase all of the output fromthesefacilities.During the fiscal year ended December 31,2000,IPC purchased862,313 MWh at a cost of$53.7 million.
The Company is party to various legal claims,actions,and complaints,certain of which involve materialamounts.Although unableto predict with certainty whether or not it will ultimately be successful in theselegalproceedings,or,if not,what the impact might be,based upon the advice of legal counsel,managementpresentlybelievesthatdispositionofthesematterswillnothaveamaterialadverseeffectontheCompany'sfinancialposition,results of operations or cash flows.
STOCK-BASEDCOMPENSATION:
In 1995,SFAS No.123,"Accounting for Stock-Based Compensation"was issued.It encourages a fair-valuebasedmethodofaccountingforstock-based compensation.As permitted by SFAS 123,the Companyadopteditsdisclosure-only requirementsand continues to account for stock-based compensationin accordancewith theprovisionsofAccountingPrinciplesBoardOpinionNo.25,"Accounting for Stock Issued to Employees"(APB 25).
IDACORP adopted the 2000 Long-Term Incentive and Compensation Plan (LTICP)for officers,keyemployeesanddirectorsofbothIDACORPandIPC.The LTICP permits the grant of nonqualified stockoptions,incentive stock options,stock appreciation rights,restricted stock,restricted stock units,performanceunits,performance shares,and other awards.
The maximum number of shares available under the LTICP is 750,000.In 2000,IDACORP and IPC issued220,000 stock options with an exercise price equal to the market price of IDACORP's common stock on thedateofgrant.The maximum term of the options is ten years,and they vest over a five-year period.InaccordancewithAPB25,no compensation costs have been recognized for the option awards in 2000.
Stock option transactions in 2000 are summarized as follows.There were no stock option transactions in1999:
Weighted
Number of average
shares exercise priceBeginningofyear..........................--Options granted ..............................220,000 $35.8125Optionsexercised...........................--Options cancelled .........................--
End of year ...............................220,000 $35.8125
Exercisable ............................-
IPC has a restricted stock plan for certain key employees.Each grant made under this plan has a three-yearrestrictedperiod,and the final awardamounts depend on the attainment of cumulative earningsper shareperformancegoals.At December 31,2000 there were 265,766 remaining shares available under this plan.
Restricted stock awards are compensatory awards and the Company accrues compensation expense (which ischargedtooperations)based upon the market value of the granted shares.For the years 2000 and 1999,totalcompensationaccruedundertheplanwas$1.5 million and $0.5 million respectively.
123-8
Idaho Power Company An Original December 31,2000
The following table summarizes restricted stock activity for the years 2000 and 1999:
2000 1999
Shares outstanding -beginning of year ...............................43,615 43,063
Shares granted.................................34,649 23,497
Shares forfeited ......................-(9,585)
Shares issued......................................(24,709)(13,360)
Shares outstanding -end of year .................................53,555 43,615
Weighted average fair value of current year
stock grants on grant date....................................$34.44 $32.88
Fair value of options granted................$8.42
BENEFIT PLANS:
Pension Plans
IPC has a noncontributory defined benefit pension plan covering most employees.The benefits under the plan
are based on years of service and the employee's final averageearnings.The Company's policy is to fund
with an independent corporate trustee at least the minimum required under the Employee Retirement Income
Security Act of 1974 but not more than the maximum amount deductible for income tax purposes.The
Company was not required to contribute to the plan in 2000 and 1999.The trustee invests the plan's assets
primarily in listed stocks (both U.S.and foreign),fixed income securities and investment grade real estate.
IPC has a nonqualified,deferred compensation plan for certain senior managementemployees and directors.
The Company financed this plan by purchasing life insurance policies and investments in marketable
securities,all of which are held by a trustee.The cash value of the policies and investments exceed the
projected benefit obligationof the plan but do not qualify as plan assets in the actuarial computation of the
funded status.
The following table shows the componentsof net periodic benefit cost for these plans (in thousands of dollars):
Deferred Compensation
Pension Plan Plan
2000 1999 2000 1999
Service cost.........................................$7,442 $8,389 $574 $744
Interest cost.........................................16,718 16,402 1,965 1,797
Expected return on assets....................(30,095)(25,240)
Recognized net actuarial (gain)loss ...(4,503)(344)242 279
Amortization of prior service cost ......708 708 (353)(325)
Amortization of transition asset..........(263)(263)613 613
Net periodic pension cost....................$(9,993)$(348)$3,041 $3,108
123-9
Idaho Power Company An Original December 31,2000
The following table summarizes the changes in benefit obligation and plan assets of these plans (in thousandsofdollars):
Pension Plan Deferred Compensation Plan
2000 1999 2000 1999Changeinprojectedbenefitobligation:Benefit obligation at January 1.................$229,042 $253,729 $26,925 $27,029Servicecost......................................7,442 8,389 574 744Interestcost....................................16,718 16,402 1,965 1,797Actuarialloss(gain)...............................455 (33,014)840 (489)Benefits paid.......................................(12,376)(16,464)(2,516)(2,201)Plan amendments..........................--88 45BenefitobligationatDecember31...........241,281 229,042 27,876 26,925Changeinplanassets:
Fair value at January 1..............................340,521 290,080 --Actual return on plan assets......................12,644 66,905Employercontributions........
Benefit payments......................................(12,376)(16,464)--Fair value at December 31........................340,789 340,521
Funded status.............................................99,508 111,479 (27,876)(26,925)Unrecognized actuarial loss (gain)...................(85,648)(108,057)6,442 5,844Unrecognizedpriorservicecost.......................7,954 8,662 (355)(796)Unrecognized net transition liability................(1,178)(1,441)2,762 3,375Netamountrecognized....................................$20,636 $10,643 $(19,027)$(18,502)
Amounts recognized in the statement of
financial position consist of:
Prepaid (accrued)pension cost ........................$20,636 $10,643 $(26,365)$(25,815)Intangible asset .........................................--2,407 2,579Accumulatedothercomprehensiveincome......--4,931 4,734Netamountrecognized....................................$20,636 $10,643 $(19,027)$(18,502)
The following table sets forth the assumptions used at the end of each year for all IPC-sponsored pension andpostretirementbenefitplans:
Pension Benefits Postretirement Benefits
2000 1999 2000 1999Discountrate.......................................................7.5%7.5%7.5%7.5%Expected long-term rate of return on assets ..........9.0 9.0 9.0 9.0Annualsalaryincreases.........................................4.5 4.5 --
Savings Plan
IDACORP has an Employee SavingsPlan which complies with Section 401(k)of the Internal RevenueCodeandcoverssubstantiallyallemployees.The Companymatches specified percentagesof employeecontributionstotheplan.Matching contributions amountedto $3.4 million in 2000 and $3.1 million in 1999.
Postretirement Benefits
The Company maintains a defined benefit postretirement plan (consisting of health care and death benefits)that covers all employeeswho were enrolled in the active group plan at the time of retirement,their spousesandqualifyingdependents.
123-10
Idaho Power Company An Original December 31,2000
The net periodic postretirement benefit cost was as follows (in thousands of dollars):
2000 1999
Service cost...........................................$851 $896
Interest cost.......................................3,374 2,867
Expected return on plan assets .............................................(2,522)(2,230)
Amortization of unrecognized transition obligation.................2,040 2,040
Amortization of prior service cost.....................................(691)(691)
Amortization of unrecognized net gains........
Net periodic post-retirement benefit cost.................................$3,052 $2,882
The following table summarizes the changes in benefit obligationand plan assets (in thousands of dollars):
2000 1999
Change in accumulated benefit obligation:
Benefit obligation at January 1...........................................$41,139 $38,615
Service cost...................................851 896
Interest cost...................................3,374 2,867
Plan amendments................................1,200 -
Actuarial loss ....................................5,635 1,859
Benefits paid...............................................(3,393)(3,098)
Benefit obligation at December 31..........................................48,806 41,139
Change in plan assets:
Fair value of plan assets at January 1........................................26,805 24,346
Actual (loss)return on plan assets .........................................(760)2,389
Employer contributions .......................................3,108 2,845
Benefits paid.......................................................(3,082)(2,775)
Fair value of plan assets at December 31..................................26,071 26,805
Funded status...........................................(22,735)(14,334)
Unrecognized prior service cost .......................................(7,336)(9,227)
Unrecognized actuarial loss (gain)....................................3,361 (5,556)
Unrecognized transition obligation ..........................................24,480 26,520
Accrued benefit obligations
included with other deferred credits ...........................................$(2,230)$(2,597)
The assumed health care cost trend rate used to measure the expected cost of benefits covered by the plan is
6.75%.A one-percentagepoint change in the assumed health care cost trend rate would have the following
effect (in thousandsof dollars):
1-Percentage-Point 1-Percentage-Point
increase decrease
Effect on total of service and interest cost components .....................$320 $(263)
Effect on accumulated postretirement benefit obligation...................$2,876 $(2,452)
Postemployment Benefits
The Company provides certain benefits to former or inactive employees,their beneficiaries,and covered
dependents after employment but before retirement.These benefits include salary continuation,health care
and life insurance for those employees found to be disabled under our disability plans,and health care for
surviving spouses and dependents.The Company accrues a liability for such benefits.In accordancewith an
IPUC order,the portion of the liability attributable to regulated activities in Idaho as of December 31,1993,
was deferred as a regulatory asset,and is being amortized over ten years.The following table summarizes
postemployment benefit amounts included in the Company's consolidated balance sheet (in thousands of
dollars):
2000 1999
Included with regulatory assets -other.......................$1,517 $1,889
Included with other deferred credits...........................$(3,040)$(3,282)
123-11
Idaho Power Company An Original December 31,2000
UTILITY PLANT IN SERVICE AND JOINTLY-OWNEDPROJECTS:The following table sets out the major classifications of the IPC's utility plant in service,accumulatedprovisionfordepreciationandannualdepreciationprovisionsasapercentofaveragedepreciablebalance fortheyears2000and1999(in thousands of dollars):
2000 1999
Balance Avg Rate Balance Avg Rate
Production........................................$1,360,409 2.60%$1,348,531 2.60%Transmission.................................410,315 2.30 403,010 2.30Distribution...............................811,604 3.34 786,488 3.37GeneralandOther.............................217,546 5.42 187,997 5.46Totalinservice..............................2,799,874 2.94%2,726,026 2.94%Accumulated provision
for depreciation.............................(1,142,572)(1,073,722)In service -net...........................$1,657,302 $1,652,304
IPC is involved in the ownership and operation of threejointly-owned generating facilities.The ConsolidatedStatementsofIncomeincludeIPC's proportionate share of direct operation and maintenance expensesapplicabletotheprojects.Each facility and extent of IPC participation as of December 31,2000 are asfollows:
Company Ownership
AccumulatedUtilityPlantInProvisionforNameofPlantLocationServiceDepreciation _%_MW
(Thousands of Dollars)
Jim Bridger Units 1-4............Rock Springs,WY 393,786 $209,986 33 707Boardman..............................Boardman,OR 62,382 36,022 10 55ValmyUnits1and2..............Winnemucca,NV 300,852 148,l15 50 261
IPC's wholly owned subsidiary,Idaho Energy Resources Company,is a jointventurer in Bridger CoalCompany,which operates the mine supplying coal for the Jim Bridger steam generation plant.Coal purchasedbyIPCfromthejointventureamountedto$43.7 million in 2000 and $41.9 million in 1999.
IPC has contracts to purchasethe energy from four PURPA Qualified Facilities that are 50 percent owned byIda-West Energy Company,a wholly owned subsidiary of IDACORP.Power purchasedfrom these facilitiesamountedto$8.1 million in 2000 and $8.8 million in 1999.
123-12
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS
Line Classifica i
1RDEPRECIATION.AMORTIZATION AND DEPLET
a Electric
No (a)(b)(c)
1 Utility Plant MINIl IUrmRR¾iß¾kWA i dÞ¾¾illtBRANWW:
2 In Service
3 Plant in Service (Classified)2,800,328,722 2,800,328,722
4 Property Under Capital Leases
5 Plant Purchased or Sold
6 Completed Construction not Classified
7 Experimental Plant Unclassified
8 Total (3 thru 7)2,800,328,722 2,800,328,722
9 Leased to Others
10 Held for Future Use 2,167,484 2,167,484
11 Construction Work in Progress 131,238,324 131,238,324
12 Acquisition Adjustments -454,449 -454,449
13 Total Utility Plant (8 thru 12)2,933,280,081 2,933,280,081
14 Accum Prov for Depr,Amort,&Depl 1,142,572,365 1,142,572,365
15 Net Utility Plant (13 less 14)1,790,707,716 1,790,707,716
16 Detail of Accum Prov for Depr,Amort &Depl
17 in Service:
18 Depreciation 1,131,355,045 1 131,355,045
19 Amort &Depl of Producing Nat Gas Land/Land Right
20 Amort of Underground Storage Land/Land Rights
21 Amort of Other Utility Plant 11,408,564 11,408,564
22 Total In Service (18 thru 21)1,142,763,609 1 142 763,609
23 Leased to Others
24 Depreciation
25 Amortization and Depletion
26 Total Leased to Others (24 &25)
27 Held for Future Use
28 Depreciation
29 Amortization
30 Total Held for Future Use (28 &29)
31 Abandonment of Leases (Natural Gas)
32 Amort of Plant Acquisition Adj -191,244 -191,244
33 Total Accum Prov (equals 14)(22,26,30,31,32)1,142,572,365 1,142,572,365
FERC FORM NO.1 (ED.12-89)Page 200
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,000
SUMMARY OF UTILITY PLANTAND ACCUMULATED PROVISIONSFORDEPRECIATION.AMORTIZATION AND DEPLETION
Gas Other (Specify)Other (Specify)Other (Specify)Common Line
(d)(e)(f)(g)(h)No.
2
3
4
5
6
7
8
9
10
11
12
13
14
15
-«16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
-31
32
33
FERC FORM NO.1 (ED.12-89)Page 201
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106)
1.Report below the original cost of electric plant in service according to the prescribed accounts.
2.In addition to Account 101,Electric Plant in Service (Classified),this page and the next include Account 102,Electric Plant Purchased or Sold;
Account 103,Experimental Electric Plant Unclassified;and Account 106,Completed Construction Not Classified-Electric.
3.Include in column (c)or (d),as appropriate,corrections of additions and retirements for the current or preceding year.
4.Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
5.Classify Account 106 according to prescribed accounts,on an estimated basis if necessary,and include the entries in column (c).Also to be included
in column (c)are entries for reversals of tentative distributions of prior year reported in column (b).Likewise,if the respondent has a significant amount
of plant retirements which have not been classified to primary accounts at the end of the year,include in column (d)a tentative distribution of such
retirements,on an estimated basis,with appropriate contra entry to the account for accumulated depreciation provision.Include also in column (d)
reversals of tentative distributions of prior year of unclassified retirements.Show in a footnote the account distributions of these tentative classifications
in columns (c)and (d),including the reversals of the prior years tentative account distributions of these amounts.Careful observance of the above
Line Account Balance Additions
No.Beginning of Year
(a)(b)(c)
1 1.INTANGIBLE PLANT
2 (301)Organization 6,684 -2
3 (302)Franchises and Consents 3,011,256 5,824,622
4 (303)Miscellaneous Intangible Plant 24,769,832 18,739,880
5 TOTAL Intangible Plant (Enter Total of lines 2,3,and 4)27,787,772 24,564,500
6 2.PRODUCTION PLANT
7 A.Steam Production Plant
8 (310)Land and Land Rights 1,275,203
9 (311)Structures and Improvements 128,423,349 413,823
10 (312)Boiler Plant Equipment 430,432,509 2,711,404
11 (313)Engines and Engine-Driven Generators
12 (314)Turbogenerator Units 105,895,644 1,280,077
13 (315)Accessory Electric Equipment 61,384,313 6,971
14 (316)Misc.Power Plant Equipment 10,115,201 101,262
15 TOTAL Steam Production Plant (Enter Total of lines 8 thru 14)737,526,219 4,513,537
16 B.Nuclear Production Plant
17 (320)Land and Land Rights
18 (321)Structures and Improvements
19 (322)Reactor Plant Equipment
20 (323)Turbogenerator Units
|
21 (324)Accessory Electric Equipment
22 (325)Misc.Power Plant Equipment
23 TOTAL Nuclear Production Plant (Enter Total of lines 17 thru 22)
24 C.Hydraulic Production Plant §.
''
25 (330)Land and Land Rights 13,960,061
26 (331)Structures and Improvements 124,142,947 1,831,014
27 (332)Reservoirs,Dams,and Waterways 240,548,951 295,005
28 (333)Water Wheels,Turbines,and Generators 179,697,905 1,562,624
29 (334)Accessory Electric Equipment 32,277,245 3,166,141
30 (335)Misc.Power PLant Equipment 12,811,672 430,158
31 (336)Roads,Railroads,and Bridges 6,933,691
32 TOTAL Hydraulic Production Plant (Enter Total of lines 25 thru 31)610,372,472 7,284,942
33 D.Other Production Plant
34 (340)Land and Land Rights
35 (341)Structures and Improvements 11,959
36 (342)Fuel Holders,Products,and Accessories 61,306
37 (343)Prime Movers
38 (344)Generators 521,947
39 (345)Accessory Electric Equipment 37,055
FERC FORM NO.1 (ED.12-95)Page 204
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106)(Continued)
instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent's plant actually in service at end ofyear.
6.Show in column (f)reclassifications or transfers within utility plant accounts.Include also in column (f)the additions or reductions of primary accountclassificationsarisingfromdistributionofamountsinitiallyrecordedinAccount102,include in column (e)the amounts with respect to accumulatedprovisionfordepreciation,acquisition adjustments,etc.,and show in column (f)only the offset to the debits or credits distributed in column (f)to primaryaccountclassifications.
7.For Account 399,state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showingsubaccountclassificationofsuchplantconformingtotherequirementofthesepages.
8.For each amount comprising the reported balance and changes in Account 102,state the property purchased or sold,name of vendor or purchase,and date of transaction.If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts,give also date
of such filing.
Retirements Adjustments Transfers Balance at LineEndofYearNo(d)(e)(f)(g)
6,682 2
8,835,878 3
88,366 43,421,346 4
88,366 52,263,906 5
1,275,203 8
16,932 128,820,240 '9
406,658 432,737,255 10
638,018 -638,018 11
107,175,721 12
61,391,284 13
2,205,317 12,421,780 14
1061,608 2,205,317 743,183,465 15
16
17
18
19
20
21
22
23
'$~'''24
13,960,061 25
125,973,961 26 I
55,688 240,788,268 27
3,508 181,257,021 28
942,552 34,500,834 29
62,065 13,179,765 30
6,933,691 31
1,063,813 616,593,601 32
33
34
11,959 35
61,306 36
37
521,947 38
37,055 39
FERC FORM NO.1 (ED.12-95)Page 205
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)20 0IdahoPowerCompanyDec.31,0
(2)A Resubmission 04/30/2001
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106)(Continued)
Line Account Balance Additions
No.Beginning of Year
(a)(b)(c)
40 (346)Misc.Power Plant Equipment 143
41 TOTAL Other Prod.Plant (Enter Total of lines 34 thru 40)632,410
42 TOTAL Prod.Plant (Enter Total of lines 15,23,32,and 41)1,348,531,101 11,798,479
43 3.TRANSMISSION PLANT
44 (350)Land and Land Rights 10,523,576 1,371,879
45 (352)Structures and Improvements 21,847,807 691,806
46 (353)Station Equipment 165,380,725 3,306,456
47 (354)Towers and Fixtures 51,629,800 990,376
48 (355)Poles and Fixtures 67,872,867 1,236,167
49 (356)Overhead Conductors and Devices 85,434,632 2,462,861
50 (357)Underground Conduit
51 (358)Underground Conductors and Devices
52 (359)Roads and Trails 320,552
53 TOTAL Transmission Plant (Enter Total of lines 44 thru 52)403,009,959 10,059,545
54 4.DISTRIBUTION PLANT
55 (360)Land and Land Rights 1,793,170 146,859
56 (361)Structures and Improvements 11,291,061 471,719
57 (362)Station Equipment 91,728,376 4,685,466
58 (363)Storage Battery Equipment
59 (364)Poles,Towers,and Fixtures 156,638,006 2,910,322
60 (365)Overhead Conductors and Devices 84,021,047 588,628
61 (366)Underground Conduit 23,106,631 2,312,708
62 (367)Underground Conductors and Devices 107,268,063 4,686,031
63 (368)Line Transformers 232,862,101 10,380,089
64 (369)Services 36,306,753 2,511,587
65 (370)Meters 35,687,437 2,468,118
66 (371)installations on Customer Premises 2,106,649 4,291
67 (372)Leased Property on Customer Premises
68 (373)Street Lighting and Signal Systems 3,679,029 16,500
69 TOTAL Distribution Plant (Enter Total of lines 55 thru 68)786,488,323 31,182,318
70 5.GENERAL PLANT
71 (389)Land and Land Rights 8,778,649 1,980
72 (390)Structures and Improvements 52,546,613 1,084,810
73 (391)Office Furniture and Equipment 33,339,352 5,457,343
74 (392)Transportation Equipment 31,182,131 4,111,695
75
¡
(393)Stores Equipment 858,315 4,699
76 (394)Tools,Shop and Garage Equipment 2,849,463 72,441
77 (395)Laboratory Equipment 7,088,269 197,946
78 (396)Power Operated Equipment 7,465,092 376,161
79 (397)Communication Equipment 14,771,385 422,591
80 (398)Miscellaneous Equipment 1,784,297 55,715
81 SUBTOTAL (Enter Total of lines 71 thru 80)160,663,566 11,785,381
82 (399)Other Tangible Property
83 TOTAL General Plant (Enter Total of lines 81 and 82)160,663,566 11,785,381
84 TOTAL (Accounts 101 and 106)2,726,480,721 89,390,223
85 (102)Electric Plant Purchased (See Instr.8)
86 (Less)(102)Electric Plant Sold (See Instr.8)
87 (103)Experimental Plant Unciassified
88 TOTAL Electric Plant in Service (Enter Total of lines 84 thru 87)2,726,480,721 89,390,223
FERC FORM NO.1 (ED.12-95)Page 206
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)0IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,200
ELECTRIC PLANT IN SERVICE (Account 101,102,103 and 106)(Continued)
Retirements Adjustments Transfers Balance at Line
(d)(e)(f)End f Year No.
143 40
632,410 41
2,125,421 2,205,317 1,360,409,476 42
19,976 11,875,479 44
7,477 -105,128 22,427,008 45
1,381,201 167,305,980 46
476 52,619,700 47
894,409 68,214,625 48
346,235 87,551,258 49
50
51
320,552 52
2,649,774 -105,128 410,314,602 53
54
2,258 1,937,771 55
81,427 11,681,353 56
977,315 71,359 95,507,886 57
58
1,170,299 158,378,029 59
595,366 84,014,309 60
81,566 25,337,773 61
585,247 111,368,847 62
1,064,737 35,157 242,212,610 63
213,989 38,604,351 64
1,291,914 36,863,641 65
77,417 2,033,523 66
67
31,563 3,663,966 68
6,173,098 106,516 811,604,059 69
l'70
12,083 8,768,546 71
802,890 52,828,533 72
1,669,676 -1,388 37,125,631 73
1,386,050 -208,932 33,698,844 74
18,451 844,563 75
42,625 2,879,279 .76
123,285 7,162,930 77
101,474 -1,996,385 5,743,394 78
303,449 14,890,527 79
45,579 1,794,433 80
4,505,562 -2,206,705 165,736,680 81
82
4,505,562 -2,206,705 165,736,680 83
15,542,221 2,800,328,723 84
85
86
87
15,542,221 2,800,328,723 88
FERC FORM NO.1 (ED.12-95)Page 207
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
1.Report separately each property held for future use at end of the year having an original cost of $250,000 or more.Group other items of property held
for future use.
2.For property having an original cost of $250,000 or more previously used in utility operations,now held for future use,give in column (a),in addition to
other required information,the date that utility use of such property was discontinued,and the date the original cost was transferred to Account 105.
Line Description and Location Date Originally Included Date Expected to be used Balance at
No.Of Property in This Account in Utility Service End of Year(a)(b)(c)(d)
1 Land and Rights:
2 Boise Operations Center 12/31/82 768,377
3
4 Production 152,418
5
6 Transmission Stations 510,063
7
8 Transmission Lines 86,981
9
10 Distribution Stations 339,120
11
12.
13
14
15
16
17
18
19
20
21 Other Property:
22 Boise Operations Center 12/31/82 72,785
23
24 Transmission Stations 12/31/81 178.094
25
26 Distribution Stations 59,646
27
28
29
30
31 Column B if no date listed it is various
32
33 Column C is unknown
34
35
36
37
38
39
40
41
42
43
44
45
46
47 Total 2,167,484
FERC FORM NO.1 (ED.12-96)Page 214
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000idahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
CONSTRUCTION WORK IN PROGRESS --ELECTRIC (Account 107)
1.Report below descriptions and balances at end of year of projects in process of construction (107)2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (seeAccount107oftheUniformSystemofAccounts)
3.Minor projects (5%of the Balance End of the Year for Account 107 or $100,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -No.Electric (Account 107)(a)(b)
1 OTHER INTANGlBLES:
2 2000 Phoenix Project 1,480,896
3 1999 PHOENIX PROJECT 1,056,755
4 ENERGY OFFICE SOFTWARE 737,026
5 FEEDER FIELDING PROJECT 585,473
6 CIS +REPORTING /DW 238,920
7 FORECAST SOFTWARE WITH SETUP &238,760
8 FLEET ANYWHERE MANAGEMENT SOFT 234,158
9 COST CENTER 342 -BUILD FEEDER 176,392
10 ABM SOFTWARE WITH SETUP &INST 165,896
11 EDMSAPI -INTERFACE TO LINK PA 150,000
12 RF INVENTORY PURCHASE -SOFTWA 150,000
13 AEGIS 123,900
14 PPPS SOFTWARE LOAN 112,142
15 PEOPLESOFT TREASURY IMPLEMENTA 106,638
16 POWER MART PURCHASE 100,000
17 OTHER 247,555
18
19 OTHER COGENERATION AND PHOTOVOLTAIC 2,358
20
21 PRODUCTION:
22 ROLLUP RELIC COST BROWNLEE 9,233,200
23 ROLLUP RELIC COST HELLS CANYON 6,610,188
24 ROLLUP RELIC COST OXBOW 2,726,301
25 BRIDGER 1999COO3 UNIT 4 TURBIN 2,190,046
26 BOARDMAN 17081 UPGRADE LP TURB 1,576,068
27 HELLS CANYON COMPLEX -RELICEN 965,266
28 HELLSCANYONCOMPLEXCULTURAL 753,330
29 ROLLUP RELIC COST LOW MALAD 699,676
30 HCC RELICENSING/REC.USE,CREE 566,632
31 HELLS CANYON COMPLEX WILDLIFE 565,670
32 HELLS CANYON COMPLEX FLOW STUD 546,117
33 VALMY 20180 #2 BURNER IMPROVEM 538,163
34 ROLLUP RELIC COST UP MALAD 451,108
35 REL -HC SEDIMENTATION STUDIES 448,941
36 AQUATIC HCC INSTREAM FLOW STUD 413.643
37 AQUATIC HCC POLLUTANT TRANSPOR 335,085
38 AQUATIC HCC WHITE STURGEON STU 328,800
39 VALMY 17631 #2 FOX 1/A ROCHEST 309,775
40 AQUATIC HCC BULL-RAINBOW TROU 305,705
41 AQUATIC HCC FEASIBILITY OF REl 302,030
42 HELLS CANYON COMPLEX TRANSMISS 296,934
43 TOTAL 131,238,324
FERC FORM NO.1 (ED.12-87)Page 216
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000idahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
CONSTRUCTION WORK IN PROGRESS --ELECTRIC (Account 107)
1.Report below descriptions and balances at end of year of projects in process of construction (107)
2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (see
Account 107 of the Uniform System of Accounts)
3.Minor projects (5%of the Balance End of the Year for Account 107 or $100,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -
No.Electric (Account 107)
(a)(b)
1 HCC INVERTEBRATE STUDY -2000 295,062
2 HELLS CANYON COMPLEX AESTHETIC 294,932
3 VALMY 17473 U2 GE MARK 3 TURBI 276,854
4 TDG STUDY CANYON COMPLEX 244,901
5 BROWNLEE-WOODHEAD PARK DESIGN 240,413
6 MALAD FISH RELICENSING STUDIES 235,740
7 REL -HC HYDROLOGlC EVALUATION 225,077
8 BRIDGER 2001TWOO8 REPLACE #4 G 216,321
9 RESERVOIR/DISCHARGE WATER QUAL 214,183
10 TSPO INSTALL GSU TF 191,591
11 AQUATIC ORNL WS PVA STUDY -20 187,747
12 BRIDGER 2000COO9 PRECIP GAS CO 182,407
13 VALMY UNDISTRIBUTED WORK ORDER 179,913
14 HCC ANADROMOUS FISH BELOW STUD 179,489
15 VALMY 17623 #2 BOILER REHEAT T 177,124
16 HELLS CANYON BIOLOGICAL OPINIO 171,404
17 JBRG186780-UNDIST WO CHARGES 162,738
18 AQUATIC DATA BASE DEVELOPMENT-159,921
19 UPPER &LOWER MALADS -RELICEN 156,886
20 HELLS CANYON COMPLEX -RL DEPT 144,129
21 BRIDGER 2000COO8 PERFORMANCE M 141,418
22 AQUATIC OXBOW HATCHERY -2000 130,871
23 AQUATIC HCC POLLUTANT SOURCE S 126,816
24 VALMY 17617 #2 BURNER DECK IMP 125,729
25 FISH PASSAGE CANYON COMPLEX 120,513
26 PURCHASE &INSTALL AN AIRCOMPR 116,656
27 AQUATIC OXBOW FALL CHINOOK HAT 115,087
28 HELLS CANYON COMPLEX WILDLIFE 110,229
29 RIVER FLOW &RESERVOIR LEVEL E 109,187
30 OTHER PRODUCTION 1,902,185
31
32 TRANSMISSION:
33 BROWNLEE-PADDOCK JCT.NEW LINE 12,751,317
34 ONTO 230 BUS 5,671,386
35 BLPR9801 BUS RECONFIGURATION 5,401,256
36 ONTARIO SERIES CAPACITOR 2,503,273
37 PHASE Ill EMS UPGRADE -ADV.A 1,534,438
38 BROWNLEE-PADDOCK JCT.NEW LINE 1,282,856
39 IPCO*MCMILLAN DOUBLE 138KV CIR 925,198
40 LCSTOOO4 HP 138 LINE TERMINAL 709,546
41 IPCO:HP-EAGLE TAP 138KV LINE 616,054
42 OASIS CONSULTING 570,109
43 TOTAL 131,238,324
FERC FORM NO.1 (ED.12-87)Page 216.1
Name of Respondent This Report Is;Date of Report Year of Report
|(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
CONSTRUCTION WORK IN PROGRESS --ELECTRIC (Account 107)
1.Report below descriptions and balances at end of year of projects in process of construction (107)
2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (seeAccount107oftheUniformSystemofAccounts)
3.Minor projects (5%of the Balance End of the Year for Account 107 or $100,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -
No.Electric (Account 107)(a)(b)
1 TSSN-lNSTALL 46/69KV STEP UP T 559,549
2 PURCHASE SERVERS FOR ACES &Pl 535,772
3 IPCO:BLACKBIRD 69KV LINE #339 325,854
4 LINE #951,REPLACE STRUCTURESI 316,569
5 IPCO*YR.2000 MAINTENANCE 138K 253,500
6 LINE #950,REPLACE 345 KV STRU 249,079
7 IPCO*JBRG-GSHN LINE #802 REPAl 245,651
8 REPLACE BRDY-ANTS GCY RELAYS 245,192
9 LINE #602,REPLACE POLES DAMAG 243,016
10 BOISE BENCH-BROWNLEE RE-RATING 240,715
11 LADD-ADD REMOTE CONTROL EQUIP 234,802
12 RIGHT-OF-WAY FOR CLOVERDALE-LO 225,031
13 IPCO:REBUILD 1 MILE OF LINE 2 219,867
14 ENERGY ACCOUNTING,ACES,AND OA 215,252
15 BOBNOO10 -REPLACE SERIES CAP 214,273
16 RIGHT OF WAY FOR DOUBLE CIRCUI 208,878
17 EMS ENHANCEMENTS PHASE IV 208.313
18 MPSN T501 MONITORING 195,904
19 APS REMEDIAL ACTION SCHEME 183,430
20 REPLACE KPRT-DONN 1 SKBU RELAY 181,236
21 ACES INSTALLATION AND DEVELOPM 168,117
22 KPRT DFR INSTALLATION 155,574
23 PTSN PROTECTION UPGRADE 152,486
24 Pl SERVER REDUNDANCY UPGRADE 152,400
25 EMS MASTER STATION UPGRADE (PH 141,832
26 MPSN DFR INSTALLATION 139,400
27 BYPASS 50%OF SERIES COMPENSAT 137,767
28 ENERGY MANAGEMENT SYSTEM (EMS 120,092
29 IPCO*PALLETTE JCT.-lMNAHA GENE 107,330
30 MLNR-EDEN LINE RELAY REPLACEME 106,062
31 REPLACE EXISTING OSCILLOGRAPH 105,203
32 IPCO*#903 MARKER BALL 101,884
33 OTHER TRANSMISSION 2,836,830
34
35 DISTRIBUTION:
36 BOISE STATE UNIVERSITY,NEW FE 1,348,916
37 MNHM-INCR CAPACITY 950,577
38 IPCO/BOBN-041 UGRADE LINE FROM 838,260
39 ADD T132 LNDN 702,015
40 LCST -ADD BKAT LINE TERMINAL,686,452
41 LNSG9901 REPLACE TO61 ADD 2 FE 655,529
42 IPCO*lDOT HAZARD CR.TO PIN 563,180
43 TOTAL 131,238,324
FERC FORM NO.1 (ED.12-87)Page 216.2
'Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000ldahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
CONSTRUCTION WORK IN PROGRESS --ELECTRIC (Account 107)
1.Report below descriptions and balances at end of year of projects in process of construction (107)
2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (see
Account 107 of the Uniform System of Accounts)
3.Minor projects (5%of the Balance End of the Year for Account 107 or $100,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -
No.Electric (Account 107)
(a).(b)
1 IPCO/BOBN-041 REBUILD FROM F-2 509,944
2 STATE HWY.69 IDOT PROJECT #ST 447,565
3 HDSP-012-41,REBUlLD STATO11 TO 439,436
4 CMBG-011,REPLACE CONDUCTOR,R 403,172
5 NWMS,RECONFIGURE 041-042 324,953
6 IPCO/BOBN-041 UPGRADE FROM HIL 313,063
7 URD NEW BUS SERVICE 1998 -CAN 305,164
8 BOGUS BASIN ENGINEERING DESIGN 303,678
9 REBUILD NEW MEADOWS TOWN SITE 300,525
10 RSETOOO1 REPLACE 4 FEEDER BREA 282,531
11 IPCO/BOBN-041 UPGRADE FROM CRO 270,830
12 IPCO:RECONDUCTOR &EXTEND HAL 263,803
13 DONNOOO1 ADD 2 FEEDERS FOR FMC 260,669
14 COUNClL:REPLACE POLES,6C &259,989
15 CNCL REPLACE TO61 245,298
16 GARY SUB -FEEDER 014A ADDITIO 238,273
17 RKFD INSTALL DCC IN STATION 221,405
18 JNCN INSTALL DCC IN STATION 216,144
19 NWMS-042 REBUILD 6 MILES,TX-2 201,887
20 IPCO/BOIS-23 REPLACE LEAKING U 178,043
21 BDSS -REWIND TRANSFORMER IPCO 177,831
22 1PCO/BOIS-021 REPLACE LEAKING 175,880
23 NEW FDR TO TRANSFER LOAD RECON 174,534
24 LNDN INSTALL DCC IN STATION 172,907
25 DONN T131 -REWIND FAILEDTRAN 171,950
26 REPLACE DONN-KPRT 1 SKBU RELAY 158,999
27 JUNIPER BUTTEIAIRFORCE BASE OH 158,233
28 IPCO,ACHD CURTIS ROAD PHASE 3 156,196
29 GARY INSTALL DCC IN STATION 154,614
30 CANYON CO.URD NEW BUS SERVICE 152,557
31 NATIVA TERRA SUBDIVISION UPG 145,109
32 BDSS -REWIND TRANSFORMER IPCO 142,449
33 CDWL INSTALL DCC IN STATION 134,430
34 CANYON CO.URD NEW BUS SERVICE 132,054
35 HSTN-lNCREASE TO61 CAPACITY 131,252
36 LCST 044-16 UB ON LINE #459 129,895
37 CSCD-012 RECONDUCTOR THUNDER C 122,120
38 PAHSIMEROl HATCHERY -99 -AQU 119,244
39 IPCO/LNSG-014 RECONDUCTOR 1 MI 117,760
40 CORRECTION WORK ORDER FOR BOC 117,546
41 PINGREE SUBSTATION CUTOVER 013 116,279
42 BOC NON CAPITAL NIS WlO 1999 113,798
43 TOTAL 131,238,324
FERC FORM NO.1 (ED.12-87)Page 216.3
Name of Respondent This Report Is:Date of Report Year of Report(1)p An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
CONSTRUCTION WORK IN PROGRESS --ELECTRIC (Account 107)
1.Report below descriptions and balances at end of year of projects in process of construction (107)2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (seeAccount107oftheUniformSystemofAccounts)
3.Minor projects (5%of the Balance End of the Year for Account 107 or $100,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -No.Electric (Account 107)(a)(b)
1 IPCO-BOBN 044-12 CABLE REPLACE 112,420
2 VTRY INSTALL DCC IN STATION 110,495
3 BOISE AIR TERMINAL ON SITE FA 107,793
4 PAUL INSTALL DCC IN STATION 106,893
5 SHSHOOO1 TO51 REPLACEMENT 100,535
6 OTHER DISTRIBUTION 8,315,045
7
8 GENERAL:
9 MAINFRAME UPGRADE 1,204,619
10 PCREPLACEMENTS&UPGRADESFOR 887,385
11 PAYROLLACCRUALADJUSTMENT 856,046
12 REPLACEOBSOLETElBM8251HUBS 537,316
13 418-COST CENTER DELIVERY CAPIT 515,005
14 BOC YARD RECONFIGURE 506,985
15 MAINFRAME UPGRADE 500,669
16 342 COST CENTER DELIVERY CAPIT 482,394
17 CONSTRUCTION ACCOUNTING CAPITA 478,993
18 COST CENTER 310 DELIVERY CAPIT 476,355
19 390 COST CENTER DELIVERY CAPIT 469,378
20 PC REPLACEMENTS &UPGRADES FOR 466,053
21 NETWORK SERVERS 443,132
22 UPGRADE SRV TAPE &DISK SPACE 440,194
23 577 COST CENTER DELIVERY CAPIT 403,720
24 371-COST CENTER DELIVERY CAPIT 365,720
25 270-COST CENTER DELIVERY CAPIT 354,539
26 100-COST CENTER DELlVERY CAPIT 353,224
27 XEROX DOCUCENTER 6135 FOR PRIN 325,279
28 410-COST CENTER DELIVERY CAPIT 301,030
29 SERVER REPLACEMENTS 299,935
30 ATM SWITCHES 298,033
31 TWO MAINFRAME UPGRADES 281,152
32 PURCHASE 1999 SPC TEST EQUIPME 276,702
33 COST CENTER 316 DELIVERY CAPIT 274,305
34 343 COST CENTER DELIVERY CAPIT 268,823
35 PURCHASE NEW NETWORK SERVERS 268,248
36 COST CENTER 320 DELIVERY CAPIT 268,116
37 COST CENTER 318 DELIVERY CAPIT 254,816
38 336-COST CENTER DELIVERY CAPIT 249,137
39 COMM-MITIGATE MOBILE RADIO INT 244,157
40 379-COST CENTER DELIVERY CAPIT 242,383
41 335-COST CENTER DELIVERY CAPIT 239,407
42 CASH REMITTANCE PROCESSING EQU 231,381
43 TOTAL 131,238,324
FERC FORM NO.1 (ED.12-87)Page 216.4
Name of Respondent This Re ort is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000idahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
CONSTRUCTION WORK IN PROGRESS --ELECTRIC (Account 107)
1.Report below descriptions and balances at end of year of projects in process of construction (107)
2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (see
Account 107 of the Uniform System of Accounts)
3.Minor projects (5%of the Balance End of the Year for Account 107 or $100,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -
No.Electric (Account 107)
(a)(b)
1 COST CENTER 321 DELIVERY CAPIT 231,231
2 374-COST CENTER DELIVERY CAPIT 226,134
3 M&E DISPATCH ADDITION 218,534
4 327-COST CENTER DELIVERY CAPIT 214,394
5 NEW UNIT 6662 -CORY SPRENGER 206,360
6 PAYETTE OPERATIONS '98 REMODEL 204,502
7 337-COST CENTER DELIVERY CAPIT 203,011
8 1999 SENTRY SOFTWARE,HARDWARE 202,992
9 372-COST CENTER DELIVERY CAPIT 199,741
10 420-COST CENTER DELIVERY CAPIT 199,489
11 FURNITURE &KI WALL FOR MARKET 198,593
12 PBX UPGRADES 197,178
13 CDDC-REPLACE RADIO CONSOLES 196,861
14 NEW UNIT 6660 -RANDY MALL -B 192,447
15 328-COST CENTER DELIVERY CAPIT 190,849
16 TOOL EXP TRANS TO CONST 188,428
17 370 -COST CENTER DELIVERY CAPI 188,350
18 COC WATER LINE EXTENTION 186,856
19 COST CENTER 317 DELIVERY CAPIT 186,553
20 DATA CENTER ADSM TAPE 185,067
21 380-COST CENTER DELIVERY CAPIT 183,582
22 CAPITAL OVERHEADS FOR CADD &A 180,579
23 415-COST CENTER DELIVERY CAPIT 178,795
24 FINANCE DEPT PCS 178,667
25 MAINFRAME,DASD &CONTROLLER T 178,210
26 576 COST CENTER DELIVERY CAPIT 177,430
27 326-COST CENTER DELIVERY CAPIT 176,327
28 PAYETTE OPERATIONS CENTER BLDG 175,736
29 152 COST CENTER DELIVERY CAPIT 175,037
30 LAB EQUIPMENT 1998 167,560
31 DON REPLACE ANALOG MICROWAVE W 164,769
32 210-COST CENTER DELIVERY CAPIT 163,509
33 392 COST CENTER DELIVERY CAPIT 162,785
34 404 COST CENTER DELIVERY CAPIT 161,506
35 COST CENTER 329 DELIVERY CAPIT 161,474
36 MEMORY FOR MAINFRAME COMPUTER 160,803
37 DELIVERY CAPITAL OVERHEADS FOR 157,803
38 373-COST CENTER DELIVERY CAPIT 157,246
39 MARKETING PC ORDER 156,659
40 LUCENT CALL MONITORING 154,445
41 334-COST CENTER DELIVERY CAPIT 154,436
42 PURCHASE GRADALL 8355 153,536
43 TOTAL 131,238,324
FERC FORM NO.1 (ED.12-87)Page 216.5
I Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000idahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
CONSTRUCTION WORK IN PROGRESS --ELECTRIC (Account 107)
1.Report below descriptions and balances at end of year of projects in process of construction (107)
2.Show items relating to "research,development,and demonstration"projects last,under a caption Research,Development,and Demonstrating (seeAccount107oftheUniformSystemofAccounts)
3.Minor projects (S%of the Balance End of the Year for Account 107 or $100,000,whichever is less)may be grouped.
Line Description of Project Construction work in progress -
No.Electric (Account 107)(a)(b)
1 PURCHASE MONITORING EQUIPMENT 152,494
2 431-COST CENTER DELIVERY CAPIT 151,704
3 PURCHASING AND U|DATING IVRU E 149,708
4 STORAGEWORKS EXPANSION -DOUBL 148,458
5 STATIONS 2000 LAB EQUIPMENT 145,649
6 378 -COST CENTER DELIVERY CAPI 145,286
7 NEW UNIT 6658 -CARY DARLING -142,210
8 WDDC-REPLACE RADIO CONSOLES 141,128
9 PBX UPGRADES &REPLACEMENTS 139,401
10 REDUNDANT SERVERS AND SOFTWARE 136,806
11 NEW UNIT 6656 -PAT EVANS -BL 136,115
12 325-COST CENTER DELIVERY CAPIT 133,528
13 DATA CENTER DISK CAPACITY UPGR 130,468
14 575 COST CENTER DELIVERY CAPIT 130,284
15 SDOC-REPLACE RADIO CONSOLES 129,033
16 DATA WAREHOUSE DEVELOPMENT 126,710
17 324-COST CENTER DELIVERY CAPIT 126,162
18 NEW UNIT 7561 -RANDY JOSEPHSO 124,434
19 HAILEY OPERATIONS DESIGN/CONST 122,656
20 346 COST CENTER DELIVERY CAPIT 122,293
21 MARKETING PURCHASES FOR Y2000 122,279
22 PUNCH PRESS FOR FAB SHOP 118,553
23 COST CENTER 290 DELIVERY CAPIT 114,654
24 PLAZA I DATA ROOM A/C ADDITION 114,106
25 TELEPHONE UPGRADES FOR DISTRIB 113,746
26 ATM HUB UPGRADES 112,784
27 376 -COST CENTER DELIVERY CAPI 111,399
28 STATION'S COMPUTER PURCHASES F 109,950
29 MAINFRAME UPGRADES FOR Y2K 109,505
30 345 COST CENTER DELIVERY CAPIT 107,354
31 458-COST CENTER DELIVERY CAPIT 107,245
32 BSPO-ADD MICROWAVE COMMUNICATI 106,704
33 SHAREOWNER'S DOCUMENT MANAGEME 106,275
34 KPRT REPLACE ANALOG MICROWAVE 106,098
35 381 -COST CENTER DELIVERY CAPI 105,873
36 455-COST CENTER DELIVERY CAPIT 105,425
37 SERVER OBSOLESCENSE AND UPGRAD 105,377
38 6TH FLOOR FURNITURE 103,359
39 MOSAIX UPGRADE 103,111
40 377 -COST CENTER DELIVERY CAPI 101,496
41 332-COST CENTER DELIVERY CAPIT 100,886
42 OTHER GENERAL -4,202,959
43 TOTAL 131,238,324
FERC FORM NO.1 (ED.12-87)Page 216.6
Name of Respondent This RORort is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
CONSTRUCTION OVERHEADS -ELECTRIC
1.List in column (a)to kinds of overheads according to the titles used by the respondent.Charges for outside professional services for engineering fees and management or supervision
fees capitalized should be shown as separate items.2.On Page 218 furnish information concerning construction overheads.3.A respondent should not report "none"to the page if no
overhead apportionments are made,but rather should explain on Page 218 the accounting procedures,employed and the amounts of engineering,supentision and administrative costs,
etc.which are directly charged to construction.4.Enter on this page engineering,supervision,administrative,and allowance for funds used during construction,etc.,which are first
assigned to a blanket work order and then prorated to construction jobs.
Line Description of overhead Total amount charged for the year
No.(a)(b)
1 Generation Overheads 206,051
2
3 Delivery Overheads 14,983,265
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL 15,189,316
FERC FORM NO.1 (ED.12-89)Page 217
This Page Intentionally Left Blank
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
GENERAL DESCRIPTION OF CONSTRUCTION OVERHEAD PROCEDURE
1.For each construction overhead explain:(a)the nature and extent of work,etc.the overhead charges are intended to cover,(b)the
general procedure for determining the amount capitalized,(c)the method of distribution to construction jobs,(d)whether different rates
are applied to different types of construction,(e)basis of differentiation in rates for different types of construction,and (f)whether the
overhead is directly or indirectly assigned.
2.Show below the computation of allowance for funds used during construction rates,in accordance with the provisions of Electric
Plant instructions 3(17)of the U.S.of A.
3.Where a net-of-tax rate for borrowed funds is used,show the appropriate tax effect adjustment to the computations below in a
manner that clearly indicates the amount of reduction in the gross rate for tax effects.
1.(a)Overhead labor and expenses directly related to construction for:
1.engineering 2.supervision 3.accounting 4.injuries and damages
(b)All charges are made direct from acounting entries to appropriate overhead accounts
except for major construction jobs carrying their own overhead accounts.
(c)Distribution of overheads is based on the percentage ratio of total overheads to direct
construction costs.
(d)(e)The same percentage rate is applied to all construction work except as described
under (f)below.
(f)Major power plants and transmission work orders,which carry their own overheads,
received direct charges for overheads which are distributed when cos is closed to
plant accounts.
COMPUTATION OF ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION RATES
For line 1(5),column (d)below,enter the rate granted in the last rate proceeding.If such is not available,use the average
rate earned during the preceding three years.
1.Components of Formula (Derived from actual book balances and actual cost rates):
Line Title Amount Capitalization Cost Rate
No.Ratio(Percent)Percentage
(a)(b)(c)(d)
1 Average Short-Term Debt &S 24,417,742
Computation of Allowance text
2 Short-term Interest s 6.54
3 Long-Term Debt D 800,469,168 49.02 d 7.61
4 Preferred Stock P 105,811,200 6.48 p 5.74
5 Common Equity C 726,596,326 44.50 c 11.00
6 Total Capitalization 1,632,876,694 100.00 100%
7 Average Construction Work in W 86,296,215
Progress Balance
2.Gross Rate for Borrowed Funds S D Ss(--)+d(-)(1--.-)4.53WD+P+C W
3.Rate for Other Funds
[1 --][p()+c (
C )]3.78
W D+P+C D+P+C
4.Weighted Average Rate Actually Used for the Year:
a.Rate for Borrowed Funds -8.60
b.Rate for Other Funds -0.00
FERC FORM NO.1 (ED.12-88)Page 218
NameofRespondent ThisRepodis:DateofRepon YearofRepon
(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTEDATA
Schedule Page:218 Line No.:8 Column:Item 2
this rate reflects the short term rate,per discussion in FERC Order 561,Docket No.75-27,where short-term borrowings have exceeded average construction work in progress.Schedule Page:218 Line No.:8 Column:Item 4a
Allowance for funds used during construction rates for 2000 (1)
Average Annual Weighted Average
Rate (2)Rate (3)Estimated Actual Estimated ActualABFDC4.470%3.604%4.486%3.967%
AOFDC 4.111%4.020%4.109%4.337%
Total AFUDC 8.581%7.624%8.595%8.304%
(1)The accounting and rate used in applying the allowance for funds used duringconstruction(AFDC)is in accordance with FERC Order No.561,Docket No.75-27 (issuedFebruary2,1977).The developmenbt of the rate for 2000 reflects the adoption of anadministrativerulingissuedtotheCompanyDecember30,1981 by FERC permittingcalculationandapplicationofmonthlyAFUDCrates.
(2)Reflects the simlpe average of the twelve monthly AFUDC rates for 2000.
(3)Reflects the weighted average effective AFUDC rates for 2000 based upon theconstructionworkinprogressbalancestowhichthemonthlyratewereapplied.
(4)A variance of more than 25 basis points exists between estimated and actual.This isduetotheclosingoftheCIS(Customer Information System)work order in November.
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
1.Explain in a footnote any important adjustments during year.
2.Explain in a footnote any difference between the amount for book cost of plant retired,Line 11,column (c),and that reported for
electric plant in service,pages 204-207,column 9d),excluding retirements of non-depreciable property.
3.The provisions of Account 108 in the Uniform System of accounts require that retirements of depreciable plant be recorded when
such plant is removed from service.If the respondent has a significant amount of plant retired at year end which has not been recorded
and/or classified to the various reserve functional classifications,make preliminary closing entries to tentatively functionalize the book
cost of the plant retired.In addition,include all costs included in retirement work in progress at year end in the appropriate functional
classifications.
4.Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Section A.Balances and Changes During Year
Line Item Total Electnc Plant in Electnc Plant Held Electnc Plant(c+d+e)Service for Future Use Leased to OthersNo(a)(b)(c)(d)(e)
1 Balance Beginning of Year 1,066,360,079 1,066,360,079
2 Depreciation Provisions for Year,Charged to
3 (403)Depreciation Expense 76,404,461 76 404 461
4 (413)Exp.of Elec.Plt.Leas.to Others
5 Transportation Expenses-Clearing 2,612,902 2 612 902 "
6 Other Clearing Accounts
7 Other Accounts (Specify):
8 account 151 Fuel Stock 159,933 159,933
9 TOTAL Deprec.Prov for Year (Enter Total of 79,177,296 79,177,296
lines 3 thru 8)
10 Net Charges for Plant Retired:
11 Book Cost of Plant Retired 15,437,107 15,437,107
12 Cost of Removal 1,722,492 1,722,492
13 Salvage (Credit)2,977,269 2,977,269
14 TOTAL Net Chrgs.for Plant Ret.(Enter Total 14,182,330 14,182,330
of lines 11 thru 13)
15 Other Debit or Cr.Items (Describe):
16
17 Balance End of Year (Enter Totals of lines 1,1,131,355,045 1,131,355,045
9,14,15,and 16)
Section E.Balances at End of Yet r According to Function3l Classification
18 Steam Production 391,108,804 391,108,804
19 Nuclear Production
20 Hydraulic Production-Conventional 213,410,123 213,410,123
21 Hydraulic Production-Pumped Storage
22 Other Production 618,411 618,411
23 Transmission 169,682,427 169,682,427
24 Distribution 308,746,082 308,746,082
25 General 47,789,198 47,789,198
26 TOTAL (Enter Total of lines 18 thru 25)1,131,355,045 1,131,355,045
FERC FORM NO.1 (ED.12-88)Page 219
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
NONUTILITY PROPERTY (Account 121;
1.Give a brief description and state the location of Nonutility property included in Account 121.
2.Designate with a double asterisk any property which is Leased to another company.State name of Lessee and whether Lessee is an associated
company.
3.Furnish particulars (details)concerning sales,purchases,or transfers of Nonutility Property during the year.
4.List separately all property previously devoted to public service and give date of transfer to Account 121,Nonutility Property.
5.Minor Items (5%of the Balance at the End of the Year),for Account 121 or $100,000,whichever is Less)may be-grouped by (1)previously devotedtopublicservice(Line 44),or (2)other Nonutility property (Line 45).
Line Description and Location Balance of Begining Purchases,Sales,Balance at EndNoofYearTransfers,etc.of Year(a)(b)(c)(d)
1 Boise Bench Transmission Station 102,812 102,812
2 transferred to account 121 in 1958
3
4 Canyon Operation Center 140,499 140,499
5 transferred to account 121 in 1985
6
7 Cascade Office,Warehouse &Garage 68,417 -68,417
8 transferred to account 121 in 1997
9|
10 Corporate Headquarters 106,328 106,328
11 transferred to account 121 in 1997
12
13 Houston office 302,880 -302,880
14 transferred to account 121 in 1999
15
16 Hunt transmission station 79,963 79,963
17 transferred to account 121 in 1978
18
19 Milner Power Plant 81,455 81,455
20 transferred to account 121 in 1993
21
22 Pioneer steam plant 46,035 46,035
23 transferred to account 121 in 1980
24
25 Nyssa Office
26 transferred to account 121 in 2000 221,557 221.557
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44 Minor Item Previously Devoted to Public Service 6,751 17,837 24,588
45 Minor Items-Other Nonutility Property 317,469 -18,834 298,635
46 TOTAL 1,252,609 -150,737 1,101,872
FERC FORM NO.1 (ED.12-95)Page 221
\Name of Respondent This Re ort is:Date of Report Year of Report
Idaho Power Company
)R u
malssion lo30DaY1r)Dec.31,2000
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
1.Report below investments in Accounts 123.1,investments in Subsidiary Companies.
2.Provide a subheading for each company and List there under the information called for below.Sub -TOTAL by company and give a TOTAL in
columns (e),(f),(g)and (h)
(a)Investment in Securities -List and describe each security owned.For bonds give also principal amount,date of issue,maturity and interest rate.
(b)Investment Advances -Report separately the amounts of loans or investment advances which are subject to repayment,but which are not subject to
current settlement.With respect to each advance show whether the advance is a note or open account.List each note giving date of issuance,maturity
date,and specifying whether note is a renewal.
3.Report separately the equity in undistributed subsidiary earnings since acquisition.The TOTAL in column (e)should equal the amount entered for
Account 418.1.
Line Description of investment Date Acquired DMaateOfy Amouen fNinvestmeeanrtat
No (a)(b)(c)r (d)
1 ldaho Energy Resources Company
2 Common Stock 02/01/74 500
3 Capital contributions 2,462,594
4 Equity in earnings 10,411,400
5
6 Subtotal Idaho Energy Resources 12,874,494
7
8 Pathnet Inc.
9 Common Stock 04/13/98 1,450,000
10 Capital contributions
11 Equity in earnings 263,892
12
13 Subtotal Pathnet Inc.1,713,892
14
15
16 IDACORP Financial Services
17 Common Stock 07/02/86 6,500,000
18 Equity in earnings 12,209,296
19 Subtotal IDACORP Financial Services 18,709,296
20 Transferred to the Holding Company IdaCorp January 2000
21
22
23 Applied Power Corporation 03/06/96
24 Common Stock 5,549,464
25 Equity in earnings -2,168,266
26 Subtotal Applied Power Corporation 3,381,198
27 Transferred to the Holding Company IdaCorp January 2000.
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42 Total Cost of Account 123.1 $3,966,293 TOTAL 36,678,880
FERC FORM NO.1 (ED.12-89)Page 224
l Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
INVESTMENT3 IN SUBSIDIARY COMPANIES (Account 123.1)(Continued)
4.For any securities,notes,or accounts that were pledged designate such securities,notes,or accounts in a footnote,and state the name of pledgeeandpurposeofthepledge.
5.If Commission approval was required for any advance made or security acquired,designate such fact in a footnote and give name of Commission,date of authorization,and case or docket number.
6.Report column (f)interest and dividend revenues form investments,including such revenues form securities disposed of during the year.
7.In column (h)report for each investment disposed of during the year,the gain or loss represented by the difference between cost of the investment(or the other amount at which carried in the books of account if difference from cost)and the selling price thereof,not including interest adjustmentincludibleincolumn(f).
8.Report on Line 42,column (a)the TOTAL cost of Account 123.1
Equity in Subsidiary Revenues for Year Amount of investment at Gain or Loss from investment LineEarninsofYearEndfYearDispsedofNo.
1
500 2
2,462,594 3
5,705,143 6,000,000 10,116,543 4
5
5,705,143 6,000,000 12,579,637 6
7
1,450,000 8
53,199 9
53,199 10
-4,642 259,250 11
12
-4,642 53,199 1,762,449 13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
5,700,501 6,053,199 14,342,086 42
FERC FORM NO.1 (ED.12-89)Page 225
I Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
MATERIALS AND SUPPLIES
1.For Account 154,report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a)
estimates of amounts by function are acceptable.In column (d),designate the department or departments which use the class of material.
2.Give an explanation of important inventory adjustments during the year (in a footnote)showing general classes of material and supplies and the
various accounts (operating expenses,clearing accounts,plant,etc.)affected debited or credited.Show separately debit or credits to stores expense
clearing,if applicable.
Line Account Balance Balance Departmentor
No.Beginning of Year End of Year Departments which
Use Material
(a)(b)(c)(d)
1 Fuel Stock (Account 151)9,328,580 5,104,792 Electric
2 Fuel Stock Expenses Undistributed (Account 152)746 86
3 Residuals and Extracted Products (Account 153)
4 Plant Materials and Operating Supplies (Account 154)
5 Assigned to -Construction (Estimated)
6 Assigned to -Operations and Maintenance
7 Production Plant (Estimated)10,094,547 9,871,226
8 Transmission Plant (Estimated)3,343,874 4,659,241
9 Distribution Plant (Estimated)7,588,008 6,124,653
10 Assigned to -Other 1,248,150 1,067,707
11 TOTAL Account 154 (Enter Total of lines 5 thru 10)22,274,579 21,722,827 Electric
12 Merchandise (Account 155)
13 Other Materials and Supplies (Account 156)
14 Nuclear Materials Held for Sale (Account 157)(Not
applic to Gas Util)
15 Stores Expense Undistributed (Account 163)3,729,950 2,961,551 Electric
16
17
18
19
20 TOTAL Materials and Supplies (Per Balance Sheet)35,333,855 29,789,256
FERC FORM NO.1 (ED.12-96)Page 227
This Page Intentionally Left Blank
Name of Respondent This Re ort is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
Line Description of Extraordinary Loss Total L WRITTEN OFF DURING YEAR Balance atNo[lnclude in the description the date of osses
aCndmpris oo rnohr aii onn(Ëo yer oc 1 AoËLousnSt DRerno9y eea co nd Amount End of Year
(a)(b)(c)(d)(e)(f)
1 None
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20 TOTAL
FERC FORM NO.1 (ED.12-88)Page 230a
'Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
Line Description of Unrecovered Plant Total Costs WRITTEN OFF DURING YEAR Balance atNo.and Regulatory Study Costs [Include Amount i Recognisedinthedescriptionofcosts,the date of of Charges During Year Account Amount End of YearCommissionAuthorizationtouseAcc182.2 Charged
and period of amortization (mo,yr to mo,yr)]
(a)(b)(c)(d)(e)(f)
21 None
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49 TOTAL
FERC FORM NO.1 (ED.12-88)Page 230b
Name of Respondent This R ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
O HER REGULATORY ASSETS (Account 182.3)
1.Report below the particulars (details)called for concerning other regulatory assets which are created through the rate making
actions of regulatory agencies (and not includable in other accounts)
2.For regulatory assets being amortized,show period of amortization in column (a)
3.Minor items (5%of the Balance at End of Year for Account 182.3 or amounts less than $50,000,whichever is less)may be grouped
by classes.
Line Description and Purpose of Debits CREDITS Balance at
No.Other Regulatory Assets Account Amount End of Year
Charged
(a)(b)(c)(d)(e)
1 Meridian Periodic Payments -IPUC 401 886,307 2,658,922
2 order #25533(amort period 1/96 thru 12/03)
3
4 Meridian initial Buyout -ID IPUC order #25533 401 408,510 1,476,167
5 (amort period 1/96 thru 12/03)
6
7 Meridian Periodic Payments -OR order #96-166 401 43,833 131,500
8 (amort period 1/96 thru 12/03)
9
10 Nez Perce Settlement -IPUC order 26513 253 1,625,000 1,625,000
11 OPUC order 96-207,FERC AC-96-131-000
12
13 Postretirement Benefits -IPUC order #25550 401 916,308 3,741,660
14 (amort period 2/95 thru 01/05)
15
16 Reorganization Costs -IPUC order 26216 401 754,057 3,771,278
17 OPUC order #95-1262 (amort 01/96 thru 12/05)
18
19 Regulatory Unfunded Accumulated Deferred Income 10,988,075 17,717,970 213,551,648
20
21 Power Cost Adjustment -IPUC order #27516 145,542,405 22,593,310 119,905,150
22 (amort period 5/98 thru 05/99)
23
24 Oregon pre-1994 Conservation -OPUC 401 55,560 157,420
25 #98448 (amort period 10/98 thru 10/03)
26
27 Nevada pre-1994 Conservation 7,568 104,621
28
29 Photvoltaic Startup IPUC order #25880 401 23,808 97,216
30 (Amort period 2/96 thru 1/06)
31
32 Northwest Energy Efficency Alliance -1999 56,422 182 86,617 41,893
33 OPUC order #98-448
34
35 Idaho -demand side management -IPUC order 401 3,242,604 30,804,767
36 #27660 (amort period 7/98 thru 6/10)
37
38 Oregon -demand side management 44,531 401 516,936 1,006,465
39 OPUC order #98-448
40
41 minor items (7)24,778 various 40,956 132,872
42
43
44 TOTAL 156,663,779 48,911,776 379,206,579
FERC FORM NO.1 (ED.12-94)Page 232
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)idaho Power Company (2)_A Resubrnission 04/30/2001 Dec 31,2000
FOOTNOTE DATA
Schedule Page:232 Line No.:19 Column:c
Account 282 15,004,970
Account 283 2,713,000
Schedule Page:232 Line No.:21 Column:c
Account 182 4,614,533
Account 401 17,644,777
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This R ort is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)Idaho Power Company Dec.31,2000
(2)A Resubmission 04/30/2001
MISCELLANEOUS DEFFERED DEBITS (Account 186)
1.Report below the particulars (details)called for concerning miscellaneous deferred debits.
2.For any deferred debit being amortized,show period of amortization in column (a)
3.Minor item (1%of the Balance at End of Year for Account 186 or amounts less than $50,000,whichever is less)may be grouped by
classes.
Line Description of Miscellaneous Balance at Debits CREDITS Balance at
No.Deferred Debits Beginning of Year Account I
'End of Year
Charged Amount
(a)(b)(c)(d)(e)(f)
1 Regional Transmsn Org -(RTO)481,919 107 3,149 478,770
2
3 Advance prepaid coal royalties 3,149,768 131 215,441 2,934,327
4
5 Benefits plan -intangible asst 2,579,634 172,303 2,407,331
6
7 Security Plan 30,571,698 1,032,155 426 1,532,791 30,071,062
8
9 American Falls bond refinance 5,299,520 4,948,078 351,442
10
11 Expense of Issue 60,986 12,335 73,321
12
13 Company owned Life Insurance 9,908,040 407,829 833,348 9,482,521
14
15 American Falls water rights 19,885,000 19,885,000
16
17 Milner bond guarantee 11,700,000 11,700,000
18
19 Southwest intertie project -6,120,165 35,681 6,155,846
20 right of way costs
21
22 CSPP receivable 3,726,783 143 492,449 3,234,334
23
24 American Falls -bond refinance 825,276 388,262 401 54,342 1,159,196
25 (35 year amortization)
26
27 Security Plan Trust 18,757,404 5,622,523 4,966,528 19,413,399
28
29 Jim Bridger -power plant 571,763 107 571,763
30
31 PacifiCorp 303,750 129,094 174,656
32
33 Valmy Power Plant 128,348 128,348
34
35 Valmy power plant -ongoing 250,383 107 250,383
36 operations
37
38 Boardman power plant -ongoing 313,868 107 313,868
39 operations
40
41 Stat Oil 1,766,675 113,991 421 1,502,093 378,573
42
43 Minor Items &Job Orders 5,654 1,285,676 various 1,174,567 116,763
44
45
46
47 Misc.Work in Progress
48 Deferred Regulatory Óomm.
Expenses (See pages 350 -351)
49 TOTAL 110,193,097 108,144,889
FERC FORM NO.1 (ED.12-94)Page 233
NameofRespondent ThisRepodis:DateofRepod YearofReport
(1)X An Original .(Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTEDATA
Schedule Page:233 Line No.:5 Column:d
Account 190 53,021
Account 216 119,282
Schedule Page:233 Line No.:9 Column:d
Account 131 44,977
Account 181 109,165
Account 186 399,155
Account 221 4,360,000
Account 401 34,781
Schedule Page:233 Line No.:13 Column:d
Account 131 525,533
Account 426 307,815
Schedule Page:233 Line No.:27 Column:d
Account 131 3,311,754
Account 186 484,891
Account 216 739,702
Account 283 126,873
Account 419 239,373
Account 421 66,935
Schedule Page:233 Line No.:31 Column:d
Account 131 70,875
Account 421 58,219
FERC FORM NO.1 (ED.12-87)Page 450
NameofRespondent This Repodls:DateofRepon YearofRepon
(1)g An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
1.Report the information called for below concerning the respondent's accounting for deferred income taxes.
2.At Other (Specify),include deferrals relating to other income and deductions.
Line Description and Location Balance of Begining Balance at End
No ofYear I ofYear
(a)(b)(c)
1 Electric
2 Contributions in Aid of Construction 4,992,755 4,865,564
3 FASB 109 Accounting 33,817,000 40,230,057
4
5
6
7 Other
8 TOTAL Electric (Enter Total of lines 2 thru 7)38,809,755 45,095,621
9 Gas
10
11
12
13
14
15 Other
16 TOTAL Gas (Enter Total of lines 10 thru 15
17 Other (Specify)See note 1 Below 23,054,041 26,576,174
18 TOTAL (Acct 190)(Total of lines 8,16 and 17)61,863,796 71,671,795
Notes
(1)Other:Beginning Balance Ending Balance
Security Plan $6,865,292 $7,043,900
Seattle City Light-CIAC 235,540 208,654
Pioneer Land (write down)237,751 45,653
'Post Retirement benefits (119,823)(44,301)
Meridian Gold contribution 314,070 335,860
Post Employment benefits 441.986 599,369
Non VEBA Pension &Benefits 981,331 918,478
Micron-CAIC 4,104,448 3,814,136
Idaho Public Utilities-Rate refund 8,690,630 3,370,638
Restricted Stock Program 257,022 706,589
Minimum Pension Liability 1,865,321 1,942,874
Gas Start-up Costs -29,460 135,907
Contingent Liability-Pwr Co Amer 235,061 0
Contingent Liability-Accident Reserve 285,324 98,388
Mark to Market-Energy Trading (1,368,485)(1,313,386)
University of Idaho 59,033 0
Dark Fiber Contracts -Def Rev 0 180,368
Contingent Liability-Marketing 0 8,533,046
FERC FORM NO.1 (E0.12-88)Page 234
This Page Intentionally Left Blank
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
CAPITAL STOCKS (Account 201 and 204)
1.Report below the particulars (details)called for concerning common and preferred stock at end of year,distinguishing separate
series of any general class.Show separate totals for common and preferred stock.If information to meet the stock exchange reporting
requirement outlined in column (a)is available from the SEC 10-K Report Form filing,a specific reference to report form (i.e.,year and
company title)may be reported in column (a)provided the fiscal years for both the 10-K report and this report are compatible.
2.Entries in column (b)should represent the number of shares authorized by the articles of incorporation as amended to end of year.
Line Class and Series of Stock and Number of shares Par or Stated Call Price at
No.Name of Stock Series Authorized by Charter Value per share End of Year
(a)(b)(c)(d)
1 Account 201
2 Common Stock registered on New York 50,000,000 2.50
3 and Pacific Stock Exchange
4 Total Common Stock 50,000,000 2.50
5
6 Account 204
7 4%Preferred Stock 215,000 100.00 104.00
8
9 Serial Preferred Stock:
10 7.68%Series (cumulative)150,000 100.00 102.97
11
12 7.07%Series (cumulative)250,000 100.00 103.53
13
14 Auction Rate Preferred Series A 500 100,000.00 100,000.00
15 Total Preferred Stock 615,500 100,300.00
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
FERC FORM NO.1 (ED.12-91)Page 250
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
CAPITAL STOCKS (Account 201 and 204)(Continued)
3.Give particulars (details)concerning shares of any class and series of stock authorized to be issued by a regulatory commissionwhichhavenotyetbeenissued.
4.The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative ornon-cumulative.
5.State in a footnote if any capital stock which has been nominally issued is nominally outstanding at end of year.Give particulars (details)in column (a)of any nominally issued capital stock,reacquired stock,or stock in sinking and other funds whichispledged,stating name of pledgee and purposes of pledge.
OUTSTANDING PER BALANCE SHEET HELD BY RESPONDENT Line(Total amount outstanding without reduction
for amounts held by respondent)AS REACQUIRED STOCK (Account 217)IN SINKING AND OTHER FUNDS No.
Shares Amount Šhares Cost Shares Amount(e)(f)(g)(h)(i)(j)
1
37,612,351 94,030,878 2
I 3
37,612,351 94,030,878 4
5
6
150,656 15,065,600 7,456 245,876 7
8
9
150,000 15,000,000 10
11
250,000 25,000,000 12
13
500 50,000,000 14
551,156 105,065,600 7,456 245,876 15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
FERC FORM NO.1 (ED.12-88)Page 251
Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
CAPITAL STOCK SUBSCRIBED,CAPITAL STOCK LIABILITY FOR CONVERSION PREMlUM ON CAPITAL AND
INSTALLMENTS RECEIVED ON CAPITAL STOCK (Accounts 202 and 205,203 and 206,207,212)
1.Show for each of the above accounts the amounts applying to each class and series of capital stock.
2.For Account 202,Common stock Subscribed,and Account 205,Preferred Stock Subscribed,show the subscription price and the balance due on
each class at the end of year.
3.Describe in a footnote the agreement and transactions under which a conversion liability existed under Account 203,Common Stock Liability for
Conversion,or Account 206,Preferred Stock Liability for Conversion,at the end of the year.
4.For Premium on Account 207,Capital Stock,designate with a double asterisk any amounts representing the excess of consideration received over
stated values of stocks without par value.
Line Name of Account and Description of Item Number of shares Amount
No.(a)(b)(c)
1 Account 202 -Common Stock Subscribed
2
3 Account 203 -Common Stock Liability for Conversion
4
5 Account 205 -Preferred Stock Subscribed
6
7 Account 206 -Preferred Stock Liability for Conversion
8
9 Account 207 -Premium on Capital Stock:
10 Premium on 4%Preferred Stock 73,053 195,178
11 Premium on Common Stock 34,012,351 361,633,705
12 Premium on 7.68%Series,Serial Preferred Stock 150,000 17,550
13
14
15
16
17 Account 212 -Installments received on capital stock
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL 34,235,404 361,846,433
FERC FORM NO.1 (ED.12-95)Page 252
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
OT BER PAID-IN CAPITAL (Accounts 208-211,inc.)
Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts.Provide asubheadingforeachaccountandshowatotalfortheaccount,as well as total of all accounts for reconciliation with balance sheet,Page 112.Add morecolumnsforanyaccountifdeemednecessary.Explain changes made in any account during the year and give the accounting entries effecting suchchange.
(a)Donations Received from Stockholders (Account 208)-State amount and give brief explanation of the origin and purpose of each donation.(b)Reduction in Par or Stated value of Capital Stock (Account 209):State amount and give brief explanation of the capital change which gave rise toamountsreportedunderthiscaptionincludingidentificationwiththeclassandseriesofstocktowhichrelated.(c)Gain on Resale or Cancellation of Reacquired Capital Stock (Account 210):Report balance at beginning of year,credits,debits,and balance at endofyearwithadesignationofthenatureofeachcreditanddebitidentifiedbytheclassandseriesofstocktowhichrelated.(d)Miscellaneous Paid-in Capital (Account 211)-Classify amounts included in this account according to captions which,together with brief explanations,disclose the general nature of the transactions which gave rise to the reported amounts.
L ne
i em A ount
1 Account 208 -Donations received from stockholders
2
3 Account 209 -Reduction in par or stated value of capital stock
4
5 Account 210 -Gain on reacquired capital stock
6 Balance January 1,2000 346,954
7
8 4%Preferred Stock (par value $100):
9 Par Value of retired Capital Stock -7,456 shares 745,600
10 Transfer premium on Capital Stock (account 207)-7,456 shares 9,693
11 Transfer capital stock expenses (account 214)-7,456 shares -17,447
12 Cost of retired capital stock (account 217)-7,456 shares -501,604
13
14
15
16
17
18
19
20
21 Account 211 -Miscellaneous Paid in Capital
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40 TOTAL 583,196
FERC FORM NO.1 (ED.12-87)Page 253
\Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)Dec.31 2000IdahoPowerCompany(2)A Resubmission 04/30/2001 '
DI3COUNT ON CAPITAL STOCK (Account 213)
1.Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
2.If any change occurred during the year in the balance with respect to any class or series of stock,attach a statement giving
particulars (details)of the change.State the reason for any charge-off during the year and specify the amount charged.
Line Class and Series of Stock 13alance at End of Year
No.(a)(b)
1 None
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21 TOTAL
FERC FORM NO.1 (ED.12-87)Page 254a
l Name of Respondent This Report Is:Date of Report Year of Report
I (1)An Original (Mo,Da,Yr)Dec.31 2000IdahoPowerCompany(2)A Resubmission 04/30/2001 '
CAPITAL STOCK EXPENSE (Account 214)
1.Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
2.If any change occurred during the year in the balance in respect to any class or series of stock,attach a statement giving particulars(details)of the change.State the reason for any charge-offof capital stock expense and specify the account charged.
Line Ölass and Šeries of Štock Balance at End of YearNo.(a)(b)
1 Common Stock 2,071,924
2
3 Preferred Stock:
4 4%(1)353,282
5 7.68%Serial 33,859
6 7.07%Serial 290,282
7 Flexible Auction Series 1,274,169
8
9
10 Explanation of Changes during the year:
11
12
13
14 (1)Charge off amount of capital stock expense applicable to retirement of 7,456 shares
15 account 210 $245,876
16
17
18
19
20
21
22 TOTAL 4,023,516
FERC FORM NO.1 (ED.12-87)Page 254b
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)
Idaho Power Company Dec.31,2000
(2)A Resubmission 04/30/2001
LONG-TERM DEBT (Account 221,222,223 and 224)
1.Report by balance sheet account the particulars (details)concerning long-term debt included in Accounts 221,Bonds,222,
Reacquired Bonds,223,Advances from Associated Companies,and 224,Other long-Term Debt.
2.In column (a),for new issues,give Commission authorization numbers and dates.
3.For bonds assumed by the respondent,include in column (a)the name of the issuing company as well as a description of the bonds.
4.For advances from Associated Companies,report separately advances on notes and advances on open accounts.Designate
demand notes as such.Include in column (a)names of associated companies from which advances were received.
5.For receivers,certificates,show in column (a)the name of the court -and date of court order under which such certificates were
issued.
6.In column (b)show the principal amount of bonds or other long-term debt originally issued.
7.In column (c)show the expense,premium or discount with respect to the amount of bonds or other long-term debt originally issued.
8.For column (c)the total expenses should be listed first for each issuance,then the amount of premium (in parentheses)or discount.
Indicate the premium or discount with a notation,such as (P)or (D).The expenses,premium or discount should not be netted.
9.Furnish in a footnote particulars (details)regarding the treatment of unamortized debt expense,premium or discount associated with
issues redeemed during the year.Also,give in a footnote the date of the Commission's authorization of treatment other than as
specified by the Uniform System of Accounts.
Line Class and Series of Obligation,Coupon Rate Principal Amount Total expense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premiumor Discount
(a)(b)(c)
1 Account 221:
2 First Mortgage Bonds:
3 6.93%Series due 2001 30,000,000 471,676
4
5
6
7 6.85%Series due 2002 27,000,000 240,493
8
9
10 6.40%Series due 2003 80,000,000 667,636
11
12 7.38%Series Due 2007 Nevada Commission UF-4111 Oregon Commission 2005-E5-93-13 80,000,000 807,871
13 Idaho Commission #IPC-E-00-15 Dated 12/31/00
14
15 7.20%Series due 2009 80,000,000 572,246
16
17 8.00%Series due 2004 50,000,000 463,337
18 400,000 D
19
20 5.83%Series due 2005 60,000,000 2,508,801
21
22 9.50%Series due 2021 75,000,000 959,890
23 375,000 D
24
25 7.50%Series due 2023 80,000,000 767,636
26 614,400 D
27
28 8 3/4%Series due 2027 50,000,000 563,337
29 187,500 D
30
31 9.52%Series due 2031 25,000,000 158,288
32
33 TOTAL 866,744,184 13,569,503
FERC FORM NO.1 (ED.12-96)Page 256
Name of Respondent This Report is:Date of Report Year of Report(1)p An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.11.Explain any debits and credits other than debited to Account 428,Amortization and Expense,or credited to Account 429,PremiumonDebt-Credit.
12.In a footnote,give explanatory (details)for Accounts 223 and 224 of net changes during the year.With respect to long-termadvances,show for each company:(a)principal advanced during year,(b)interest added to principal amount,and (c)principle repaidduringyear.Give Commission authorization numbers and dates.
13.If the respondent has pledged any of its long-term debt securities give particulars (details)in a footnote including name of pledgeeandpurposeofthepledge.
14.If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end ofyear,describe such securities in a footnote.
15.If interest expense was incurred during the year on any obligations retired or reacquired before end of year,include such interestexpenseincolumn(i).Explain in a footnote any difference between the total of column (i)and the total of Account 427,interest onLong-Term Debt and Account 430,Interest on Debt to Associated Companies.16.Give particulars (details)concerning any long-term debt authorized by a regulatory commission but not yet issued.
AMORTIZATION PERIOD Uutstandin9 LineNominalDateDateof(Total amount outstanding without Interest for YearofIssueMaturityDateFromDateToreductionrfosrpamoenntsheldbyAmount No.
(d)(e)(f)(g)Îhnd
207/29/96 07/30/01 07/29/96 07/30/01 30,000,000 2,079,000 3
4
5
6
10/02/96 10/01/02 10/02/96 10/01/02 27,000,000 1,849,500 7
8
904/28/93 05/01/03 04/28/93 05/01/03 80,000,000 5,120,000 10
1112/1/00 12/1/07 12/1/00 12/1/07 80,000,000 492,000 12
13
14
11/23/99 12/1/09 1/1/00 1/1/10 80,000,000'5,760,000 15
1603/25/92 03/15/04 03/21/92 03/15/04 50,000,000 4,000,000 17
18
1909/09/98 09/09/05 09/09/98 09/09/05 60,000,000 3,498,000 20
21
01/14/91 01/01/21 01/14/91 01/01/21 75,000,000 7,125,000 22
23
2404/28/93 05/01/23 04/28/93 05/01/23 80,000,000 6,000,000 25
26
27
03/25/92 03/15/27 03/25/92 03/15/27 50,000,000 4,375,000 28
29
30
08/19/91 08/15/31 08/19/91 08/15/31 25,000,000 2,380,000 31
32
840,384,141 53,253,094 33
FERC FORM NO.1 (ED.12-96)Page 257
Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
LONG-TERM DEBT (Account 221,222,223 and 224)
1.Report by balance sheet account the particulars (details)concerning long-term debt included in Accounts 221,Bonds,222,
Reacquired Bonds,223,Advances from Associated Companies,and 224,Other long-Term Debt.
2.In column (a),for new issues,give Commission authorization numbers and dates.
3.For bonds assumed by the respondent,include in column (a)the name of the issuing company as well as a description of the bonds.
4.For advances from Associated Companies,report separately advances on notes and advances on open accounts.Designate
demand notes as such.Include in column (a)names of associated companies from which advances were received.
5.For receivers,certificates,show in column (a)the name of the court -and date of court order under which such certificates were
issued.
6.In column (b)show the principal amount of bonds or other long-term debt originally issued.
7.In column (c)show the expense,premium or discount with respect to the amount of bonds or other long-term debt originally issued.
8.For column (c)the total expenses should be listed first for each issuance,then the amount of premium (in parentheses)or discount.
Indicate the premium or discount with a notation,such as (P)or (D).The expenses,premium or discount should not be netted.
9.Furnish in a footnote particulars (details)regarding the treatment of unamortized debt expense,premium or discount associated with
issues redeemed during the year.Also,give in a footnote the date of the Commission's authorization of treatment other than as
specified by the Uniform System of Accounts.
Line Class and Series of Obligation,Coupon Rate Principal Amount Total e×pense,
No.(For new issue,give commission Authorization numbers and dates)Of Debt issued Premium or Discount
(a)(b)(c)
1
2 Pollution control Revenue Bonds
3 7 1/4%Series due 2008 4,360,000 96,331
4 8.30%Valmy due 2014 49,800,000 2,235,221
5
6 6.05%Series 96A due 2026 68,100,000 571,895
7 471,252 D
8
9 Series '96B due 2026 24,200,000 124,587
10
11
12 Series '96C due 2026 24,000,000 123,561
13
14 Port of Morrow Variable due 2027 Nevada Commission #UF-4111 4,360,000 188,545
15 Oregon Commission 2005-E$-00-21 Idaho Commission IPC-E-00-2
16 Subtotal Account 221 811,820,000 13,569,503
17
18 Account 224:
19 Other Long-Term Debt
20
21 Bond Guarantee -American Falls 21,425,000
22
23 Bond Guarantee -American Falls Nevada Commission #UF-4169,19,885,000
24 Oregon Commission 2005-ES-00-21 Idaho Commission IPC-E-00-2 dated 11/9/00
25 Note Guarantee -Milner Dam 11,700,000
26 REA Notes 1,914,184
27 Subtotal Account 224 54,924,184
28
29 Account 222 -Reacquired Bonds
30 Account 223 -Advances from Associated Companies
31
32
33 TOTAL 866,744,184 13,569,503
FERC FORM NO.1 (ED.12-96)Page 256.1
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
LONG-TERM DEBT (Account 221,222,223 and 224)(Continued)
10.Identify separate undisposed amounts applicable to issues which were redeemed in prior years.
11.Explain any debits and credits other than debited to Account 428,Amortization and Expense,or credited to Account 429,PremiumonDebt-Credit.
12.In a footnote,give explanatory (details)for Accounts 223 and 224 of net changes during the year.With respect to long-termadvances,show for each company:(a)principal advanced during year,(b)interest added to principal amount,and (c)principle repaid ,during year.Give Commission authorization numbers and dates.
13.If the respondent has pledged any of its long-term debt securities give particulars (details)in a footnote including name of pledgeeandpurposeofthepledge.
14.If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end ofyear,describe such securities in a footnote.
15.If interest expense was incurred during the year on any obligations retired or reacquired before end of year,include such interestexpenseincolumn(i).Explain in a footnote any difference between the total of column (i)and the total of Account 427,interest onLong-Term Debt and Account 430,Interest on Debt to Associated Companies.
16.Give particulars (details)concerning any long-term debt authorized by a regulatory commission but not yet issued.
AMORTIZATION PERIOD Uutstanding..LineNominalDateDateof(Total amount outstanding without Interest for YearofIssueMaturityDateFromDateToreductionrfosrpamoenntsheldbyAmount No.
(d)(e)(f)(g)Îhnd
1
208/01/78 08/01/08 08/01/78 08/01/08 184,391 3
12/20/84 12/01/14 12/20/84 12/01/14 49,800,000 4,133,400 4
I
507/25/96 07/15/26 07/25/96 07/15/26 68,100,000 4,120,050'6
7
807/25/96 07/15/26 07/25/96 07/15/26 24,200,000 1,013,216 9
10
1107/25/96 07/15/26 07/25/96 07/15/26 24,000,000 992,703 12
13
5/17/00 2/1/27 I 5/17/00 2/1/07 4,360,000 89,495 14
15
807,460,000 53,211,755 16
17
18
19
2003/01/90 21
224/26/00 2/1/25 19,885,000 23
2402/10/92 11,700,000 25
1,339,141 41,339 26
32,924,141 41,339 27
28
29
30
31
32
840,384,141 53,253,094 33
FERC FORM NO.1 (ED.12-96)Page 257.1
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTE DATA
Schedule Page:256.1 Line No.:3 Column:a
The 7.25%series was retired in August 2000.The unamortized debt expense was included
with the new issue,of Port of Morrow Variable.
Schedule Page:256.1 Line No.:21 Column:a
The American Falls Replacement Dam Bonds,were retired in May 2000.
FERC FORM NO.1 (ED.12-87)Page450
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000idahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
1.Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and showcomputationofsuchtaxaccruals.Include in the reconciliation,as far as practicable,the same detail as furnished on Schedule M-1 of the tax return fortheyear.Submit a reconciliation even though there is no taxable income for the year.Indicate clearly the nature of each reconciling amount.
2.If the utility is a member of a group which files a consolidated Federal tax return,reconcile reported net income with taxable net income as if aseparatereturnweretobefield,indicating,however,intercompany amounts to be eliminated in such a consolidated return.State names of groupmember,tax assigned to each group member,and basis of allocation,assignment,or sharing of the consolidated tax among the group members.3.A substitute page,designed to meet a particular need of a company,may be used as Long as the data is consistent and meets the requirements oftheaboveinstructions.For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line Particulars (Details)AmountNo.(a)(b)
1 Net Income for the Year (Page 117)137,487,964
2
3
4 Taxable income Not Reported on Books
5 24,443,318
6
7
8
9 Deductions Recorded on Books Not Deducted for Return
10 -26,908,686
11
12
13
14 Income Recorded on Books Not Included in Return
15 21,372,319
16
17
18
19 Deductions on Return Not Charged Against Book Income
20 13,961,445
21
22
23
24
25
26
27 Federal Tax Net Income
28 Show Computation of Tax:99,688,832
29 Tenative Federal Tax $99,688,832 @ 35%34,891,091
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
FERC FORM NO.1 (ED.12-96)Page 261
NameofRespondent This Repodis:DateofReport YearofReport
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTEDATA
Schedule Page:261 Line No.:5 Column:b
Construction advance $-562,959
CIAC as taxable income closed to plant 30,250,000
Avoided cost int cap 2,857,936
Ciac as taxable inc in acct 107 -8,120,000
Dark fiber contracts FTV 422,412
Dark fiber contracts 458,310
Royalty income 109,150
CIAC Meridian gold -69,196
CIAC-Micron dram -821,023
CIAC-Seattle City Light -81,312
Total $24,443,318
Schedule Page:261 Line No.:10 Column:b
Total Fed an State taxed deducted on books $81,075,539
FERC headwater benefit-rev amort 435,599Gain/loss on reaquired debt-deferred -3,544,982
SFAS 112 post employment 129,734
Overaccrued vacation 625,376
Prin portion-air lease 185,200
Directors fees deferred 235,242
Pension Accrual -5,403,557
Meals 50%liminations -143,166
Meals charged to R.E.543,166
Milner falling water 264,100
Amortization of account 114 -22,723
Oregon oper property tax adj -20,036
Nonveba pen&ben -220,150
PCA expense deferral -123,283,095
Post retiree benefit 544,800
Sun Valley fac -rev amort 12,328
Restricted stock plan 756,991
Cont liab Power Company of America -600,000
Accident reserve -475,000
SEC plan -net ins costs -555,497
Nondeductible political expense 382,000
benefit accrual 525,051
Nondeductible political exp-o&m 150,000
startup &organization costs -37,848
Marketing activities 21,682,242
Donation accrued but not paid -150,000
Total $-26,908,686
FERC FORM NO.1 (ED.12-87)Page 450
NameofRespondent ThisReportis:DateofRepod YearofReport
(1)_X An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTEDATA
Schedule Page:261 Line No.:15 Column:b
Gain on sale of BOC $31,970
IPUC roe amort 6,949,489
Reverse equity earnings of subs 8,357,882
Allowance for OFUDC 2,565,391
Allowance for BFUDC 2,346,355
SEC plan and coli -proceeds 1,261,239
Mark to market -energy trading -140,007
Total $21,372,319
Schedule Page:261 Line No.:20 Column:b
Veba post retirement benefits $139,247
Depr for tax gt or lt book -16,586,956
Cap int amort 701
Conservation prpgrams -5,303,390
Nevada operating property tax adj -46,259Oregontasadjustment74,800
Removal costs 1,860,105Repairallowance13,000,000
State tax not deducted on prior return -182,281
American Falls falling water pymt 1,544,476Gain/loss on reaquired debt -426,271
State tax audit settlements paid this year 1,313
Meridian contracy buyout -302,398Reorganizationcosts-754,057
Software costs CIS 107 9,260,529
Donation capitalized on books 100,000
Photovoltaic startup costs -23,808
Research &development deduct 107 6,207,117
COLI tax adj from books -396,016Oregonnonoppropertytaxadj1,224
Depr adjustment-nonop-other 79,000
State inc tax deducted on federal return 5,644,579
Total $13,961,445
FERC FORM NO.1 (ED.12-87)Page 450.1
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2IdahoPowerCompanyDec.31,000(2)A Resubmission 04/30/2001
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR
1.Give particulars (details)of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts
during the year.Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged.If the
actual,or estimated amounts of such taxes are know,show the amounts in a footnote and designate whether estimated or actual amounts.
2.Include on this page,taxes paid during the year and charged direct to final accounts,(not charged to prepaid or accrued taxes.)
Enter the amounts in both Columns (d)and (e).The balancing of this page is not affected by the inclusion of these taxes.
3.Include in column (d)taxes charged during the year,taxes charged to operations and other accounts through (a)accruals credited to taxes accrued,
(b)amounts credited to proportions of prepaid taxes chargeable to current year,and (c)taxes paid and charged direct to operations or accounts other
than accrued and prepaid tax accounts.
4.List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
Line Kind of Tax BALANCE AT BEGINNING OF YEAR ChaarŸed Oaieds Adjust-
No.(See instruction 5)Taxes Accrued Prepaid Taxes Dunng During ments(Account 236)(Include in Account 165)Year Year(a)(b)(c)(d)(e)(f)
1 Federal:
2 Income 4,259,682 33,684,909 39,173,742
3 Social Security -(FOAB)529,460 7,833,968 8,368,572
4 Unemployment -2,390 107,952 108,151
5 Highway Use 21,763 21,763
6 Environmental -6,159 7,249
7
8 Subtotal 4,780,593 41,655,841 47,672,228
9
10 State of Idaho:
11 Property 5,870,584 12,343,191 12,645,648
12 Income -1,028,495 7,668,598 6,500,453
13 KWH 316,344 1,834,094 2,053,589
14 Unemployment -17,756 87,729 87,730
15 Regulatory Commission 1,429,834 1,429,834
16 Motor Vehicle License 16,494 16,494
17 Business License 150 150 150
18
19 Subtotal Idaho 5,140,677 150 23,380,090 22,733,898
20
21 State of Oregon
22 Property 977,524 1,924,226 1,998,086
23 Income 1,363,767 -309,160 1,047,318
24 Regulatory Commission 92,645 92,645
25 Unemployment 1,977 25,365 25,557
26 Franchise 100,086 421,935 416,958
27 Motor Vehicle 769 769
28
29 Subtotal Oregon 1,465,830 977,524 2,155,780 3,581,333
30
31 State of Montana:
32 Property 41,430 80,118 81,530
33
34 Subtotal Montana 41,430 80,118 81,530
35
36
37
38
39 State of Nevada:
40 Property 250,719 501,439 961,379 937,599
41 TOTAL 14,976,322 1,479,113 59,318,374 76,323,573
FERC FORM NO.1 (ED.12-96)Page 262
Name of Respondent This Report Is:Date of Report Year of Report(1)p An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR (Continued)
5.If any tax (exclude Federal and State income taxes)-covers more then one year,show the required information separately for each tax year,identifying the year in column (a).
6.Enter all adjustments of the accrued and prepaid tax accounts in column (f)and explain each adjustment in a foot-note.Designate debit adjustmentsbyparentheses.
7.Do not include on this page entries with respect to deferred income ta×es or taxes collected through payroll deductions or otherwise pendingtransmittalofsuchtaxestothetaxingauthority.
8.Report in columns (i)through (l)how the taxes were distributed.Report in column (I)only the amounts charged to Accounts 408.1 and 409.1pertainingtoelectricoperations.Report in column (1)the amounts charged to Accounts 408.1 and 109.1 pertaining to other utility departments andamountschargedtoAccounts408.2 and 409.2.Also shown in column (I)the taxes charged to utility plant or other balance sheet accounts.9.For any tax apportioned to more than one utility department or account,state in a footnote the basis (necessity)of apportioning such tax.
BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED Line(Taxes accrued Prepaid Taxes Electric Extraordinary Items Adjustments to Ret Other NoAccount236)(incl.in Account 165)(Account 408.1,409.1)(Account 409.3)Earnings (Account 439)(g)(h)(i)(j)(k)(1)
-1,229,151 -10,776,914 44,461,823 2-5,144 7,833,968 3-2,589 107,952 4
21,763 51,090 7,249 6
7-1,235,794 -2,834,994 44,490,835 8
9
105,568,127 12,343,191 11
139,650 -477,503 8,146,101 1296,847 1,834,094 13-17,757 87,729 14
1,429,834 15
16,494 16
150 150 17
185,786,867 150 15,217,495 8,162,595 19
20
21
998,785 1,924,226 227,289 -1,240,848 931,688 23
92,645 241,784 25,365 25105,063 421,935 26
769 27
28114,136 998,785 1,223,323 932,457 29
30
3140,018 80,118 32
3340,018 80,118 34
35
36
37
38
39226,939 453,877 961,379 40
6,183,217 1,452,812 5,593,539 53,724,835 41
FERC FORM NO.1 (ED.12-96)Page 263
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR
1.Give particulars (details)of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts
during the year.Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged.If the
actual,or estimated amounts of such taxes are know,show the amounts in a footnote and designate whether estimated or actual amounts.
2.Include on this page,taxes paid during the year and charged direct to final accounts,(not charged to prepaid or accrued taxes.)
Enter the amounts in both columns (d)and (e).The balancing of this page is not affected by the inclusion of these taxes.
3.Include in column (d)taxes charged during the year,taxes charged to operations and other accounts through (a)accruals credited to taxes accrued,
(b)amounts credited to proportions of prepaid taxes chargeable to current year,and (c)taxes paid and charged direct to operations or accounts other
than accrued and prepaid tax accounts.
4.List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
Line Kind of Tax BALANCE AT BEGINNING OF YEAR Chaaresed aieds Adjust-
No.(See instruction 5)Taxes Accrued Prepaid Taxes During During ments(Account 236)(Include in Account 165)Year Year
(a)(b)(c)(d)(e)(f)
1 Unemployment 59 59
2 Mountain City License 75 75
3 Elko County Franchise 7,287 7,287
4 Regulatory Commission 5,954 5,954
5 BusinessTax 100 100
6
7 Subtotal Nevada 250,719 501,439 974,854 951,074
8
9 State of Wyoming
10 Corporate License 3,735 3,735
11 Property 635,407 1,216,275 1,243,544
12
13 Subtotal Wyoming 635,407 1,220,010 1,247,279
14
15 misc states franchise 300
16
17 Other States income 2,661,666 -1,962,522 55,931
18 Payroll Adjustment -8,185,797
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41 TOTAL 14,976,322 1,479,113 59,318,374 76,323,573
FERC FORM NO.1 (ED.12-96)Page 262.1
'Name of Respondent This Report Is:Date of Report Year of Report(1)Q An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TAXES ACCRUED,PREPAID AND CHARGED DURING YEAR (Continued)
5.If any tax (exclude Federal and State income taxes)-covers more then one year,show the required information separately for each tax year,identifying the year in column (a).
6.Enter all adjustments of the accrued and prepaid tax accounts in column (f)and explain each adjustment in a foot-note.Designate debit adjustments
by parentheses.
7.Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pendingtransmittalofsuchtaxestothetaxingauthority.
8.Report in columns (i)through (l)how the taxes were distributed.Report in column (I)only the amounts charged to Accounts 408.1 and 409.1pertainingtoelectricoperations.Report in column (1)the amounts charged to Accounts 408.1 and 109.1 pertaining to other utility departments andamountschargedtoAccounts408.2 and 409.2.Also shown in column (1)the taxes charged to utility plant or other balance sheet accounts.
9.For any tax apportioned to more than one utility department or account,state in a footnote the basis (necessity)of apportioning such tax.
BALANCE AT IND OF YEAR DISTRIBUTION OF TAXES CHARGED Line(Taxes accrued Prepaid Taxes Electric I Extraordinary Items |Adjustments to Ret.Other No.Account 236)(Incl.in Account 165)(Account 408.1,409.1)(Account 409.3)Earnings (Account 439)(g)(h)(i)(j)(k)(I)
59 1
75 2
7,287 3
5,954 4
100 5
6
226,939 453,877 974,854 7
8
9
3,735 10
608,138 1,216,275 11
12
608,138 1,220,010 13
14
-300 15
16
643,213 -2,101,470 138,948 17
-8,185,797 18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
6,183,217 1,452,812 5,593,539 53,724,835 41
FERC FORM NO.1 (ED.12-96)Page 263.1
This Page Intentionally Left Blank
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTE DATA
Schedule Page:262 Line No.:2 Column:I
Account 409.2
Schedule Page:262 Line No.:5 Column:I
Account 184
Schedule Page:262 Line No.:6 Column:I
Account 184
Schedule Page:262 Line No.:12 Column:I
Account 409.2
Schedule Page:262 Line No.:16 Column:I
Account 184
Schedule Page:262 Line No.:22 Column:a
This line includes $52,600 charged to account 408.1,the othersideofthisentryisaccount254-not 236,therefore,the
total will not zero when calculating across.
Schedule Page:262 Line No.:23 Column:I
Account 409.2
Schedule Page:262 Line No.:27 Column:I
Account 184
Schedule Page:262.1 Line No.:17 Column:I
Account 409.2
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255.Where appropriate,segregate the balances and transactions by utility and
nonutility operations.Explain by footnote any correction adjustments to the account balance shown in column (g).Include in column (i)
the average period over which the tax credits are amortized.
Line Account Balance at Beginning Allocations to
No Subd 'ions of Year Deferred for Year Current Year's Income Adjustments
a s (b)Account No.Amount Account No.Amount(c)(d)(e)(f)(9)
1 Electric Utility
2 3%
3 4%2,360,136 178,094
4 7%
5 10%46,930,980 2,255,51A
6 1,556,059 25,053
7 16,586,098 255 1,700,000 411 624,732
10 Line 6 col A 11%
11 Line 7
I12StateofIdaho16,586,098 411 1,700,000 411 624,733
13 adjustment to 1997
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
FERC FORM NO.1 (ED.12-89)Page 266
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ACCUMULATED D:FERRED INVESTMENT TAX CREDITS (Account 255)(continued)
Balance at End Average Period ADJUSTMENT EXPLANATION LineofYearofAllocationNotoincome(h)(i)
1
2
2,182,042 13.25 3
4
44,675,466 20.81 5
1,531,006 62.11 6
17,661,365 26.55 7
66,049,879 8
10
11
17,661,365 12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
FERC FORM NO.1 (ED.12-89)Page 267
Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
O HER DEFFERED CREDITS (Account 253)
1.Report below the particulars (details)called for concerning other deferred credits.
2.For any deferred credit being amortized,show the period of amortization.
3.Minor items (5%of the Balance End of Year for Account 253 or amounts less than $10,000,whichever is greater)may be grouped by classes.
Line Description and Other Balance at DEBITS Balance at
No.Deferred Credits Beginning of Year Contra Amount Credits End of Year
Account(a)(b)(c)(d)(e)(f)
1 GST Bankruptcy 658,120 658,120
2
3 Customer Level Pay 1,985,473 142 2,149,311 1,990,416 1,826,578
4
5 US Airforce Photovoltaic Generator -318 142 9,869 47,322 37,135
6
7 Nez Perce Settlement 3,250,000 107 1,625,000 1,625,000
8
9 Security Plan 18,501,499 2,515,949 3,041,000 19,026,550
10
11 Milner Falling Water 1,872,357 264,100 2,136,457
12
13 Postretirement Benefits 3,281,814 401 241,774 3,040,040
14
15 Benefit Plan -Minimum Liability 7,313,950 24,532 7,338,482
16
17 Pathnet 142 28,786 287,861 259,075
18
19 Point to Point Transmission Study 582,750 232 632,000 458,250 409,000
20
21 FTV 1,666,666 142 400,000 1,000,000 2,266,666
22
23 Albertsons 142 28,000 140,000 112,000
24
25 Twin Falls School 142 8,804 96,038 87,234
26
27 Directors Deferred Compensation 2,449,408 232 173,918 409,161 2,684,651
28
29 Minor items -other 3,212 Various 250 2,962
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47 TOTAL 40,906,811 7,813,661 8,416,800 41,509,950
FERC FORM NO.1 (ED.12-94)Page 269
Name of Respondent This Report is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTE DATA
Schedule Page:269 Line No.:9 Column:cAccount232$2,254,262
Account 241 260,949
Account 401 738
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ACCUMULATED DEFERRED INCOME TAXES -ACCELERATED AMORTIZATION PROPER Y (Account 281)
1.Report the information called for below concerning the respondent's accounting for deferred income taxes rating to amortizable
property.
2.For other (Specify),include deferrals relating to other income and deductions.
CHANGES DURING YEAR
Line Account Balance at
No.Beginning of Year Amounts Debited Amounts Credited
to Account 410.1 to Account 411.1
(a)(b)(c)(d)
1 Accelerated Amortization (Account 281)
2 Electric
3 Defense Facilities
4 Pollution Control Facilities
5 Other
6
7
8 TOTAL Electric (Enter Total of lines 3 thru 7)
9 Gas
10 Defense Facilities
11 Pollution Control Facilities
12 Other
13
14
15 TOTAL Gas (Enter Total of lines 10 thru 14)
16
17 TOTAL (Acct 281)(Total of 8,15 and 16)
18 Classification of TOTAL
19 Federal income Tax
20 State Income Tax
21 Local income Tax
NOTES
FERC FORM NO.1 (ED.12-96)Page 272
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ACCUMULATED DEFERRED INCOrv E TAXES _ACCELERATED AMORTIZATION PROPERTY (Account 281)(Continued)
3.Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Amounts Debited Amounts Credited Debits Credits Balance at Line
to Account 410.2 to Account 411.2 Account Amount Account Amount End of Year No.Credited Debited(e)(f)(g)(h)(¡](k)
3
4
5
6
7
8
10
11
12
13
14
15
16
17
19
20
21
NOTES (Continued)
I
i
NERC FORM NO.1 (ED.12-96)Page 273
Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ACCUMULATE )DEFFERED INCOME TAXES -OTE ER PROPERTY (Account 282)
1.Report the information called for below concerning the respondent's accounting for deferred income taxes rating to property not
subject to accelerated amortization
2.For other (Specify),include deferrals relating to other income and deductions.
CHANGES DURING YEAR
Line Account Balance at
No.Beginning of Year Amounts Debited Amounts Credited
to Account 410.1 to Account 411.1
(a)(b)(c)(d)
1 Account 282
2 Electric 244,123,273 2,174,184 12,603,901
3 Gas
4 Other than Liberalized Depr 138,601,965 9,590,324 -661,554
5 TOTAL (Enter Total of lines 2 thru 4)382,725,238 11,764,508 11,942,347
6 Non-Operating Property 104,344
7
8
9 TOTAL Account 282 (Enter Total of lines 5 thru 382,829,582 11,764,508 11,942,347
10 Classification of TOTAL
11 Federal income Tax 319,278,918 11,764,509 11,924,347
12 State income Tax 63,650,663 18,000
13 Local income Tax
NOTES
ERC FORM NO.1 (ED.12-96)Page 274
Name of Respondent This Report is:Date of Report Year of Report(1)g An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ACCUMULATED DEFERRED INCOME TAXES -OTHER PROPERTY (Account 282)(Continued)3.Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTSAmountsDebitedAmountsCreditedDebits Credits Balance at LinetoAccount410.2 i to Account 411.2 Account i Amount Account i Amount End of Year No.Credited Debited(e)(f)(g)(h)(¡¡(k)
233,693,55E 2
3
182 &282 33,145,831182 &282 113,364,652 229,072,665 4
33,145,831 113,364,652 462,766,221 599,66E -27,458
,231,471 6
7
899,66E -27,45E 33,145,831 113,364,65:462,997,692 9
64,932 -22,78E 4,433,560 72,654,877 387,428,11E 1134,737 -4,66E 28,712,271 40,709,77E 75,669,574 12
13
NOTES (Continued)
FERC FORM NO.1 (ED.12-96)Page 275
This Page Intentionally Left Blank
Narne of Respondent This Report is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)_A Resubrnission 04/30/2001 Dec 31,2000
FOOTNOTE DATA
Schedule Page:274 Line No.:4 Column:b
Col B Col C Col D Col G Col H Col I Col J Col KRepairAllow1,068,385 169,200 899,185Bridger939,257 102,400 836,857NValmy1,269,266 76,500 1,192,766FERC6,350,671 337,000 6,687,671IndusDevCosts28,204 28,204CISDevCosts178,705 3,342,853 17,875 5,503,684TaxableCIAC(6,631,590)821,379 (1,113,206)(4,697,005)Software costs 94,444 715,908 85,677 724,675R&D costs 4,344,980 4,344,980FASB109133,332,825 182 33,145,831 182 33,986,243FASB109xfer28328379,378,410 213,551,648
Total Other 138,601,964 9,590,325 (661,554)33,145,831 33,986,243 229,072,665
The FASB 109 transfer balance was transferred to account 282 from account 283 in 2000,
FERC F()RIW hk3.1 (ED.12-87)Page450
\Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000idahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
ACCUMULATED DEFFERED INCOME TAXES -OTHER (Account 283)
1.Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts
recorded in Account 283.
2.For other (Specify),include deferrals relating to other income and deductions.
CHANGES DURING YEAR
Line Account Balance at Amounts Debited Amounts Credited
No.Beginning of Year to Account 410.1 to Account 411.1
(a)(b)(c)(d)
1 Account 283
2 Electric
3 Bald Mountain 19,350 529 5,324
4 Meridian buyout contracts 614,994 68,250 227,580
5 Weatherization grants
6 Ferc Order 144A -1,043,237 -115,100
7
8 Other 100,447,120 46,444,586 -400,139
9 TOTAL Electric (Total of lines 3 thru 8)100,038,227 46,513,365 -282,335
10 Gas
11 I
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 Other 569,401
19 TOTAL (Acct 283)(Enter Total of lines 9,17 and 18)100,607,628 46,513,365 -282,335
20 Classification of TOTAL
21 Federal income Tax 56,794,006 38,359,544 -364,681
22 State income Tax 43,813,622 8,153,821 82,346
23 Local income Tax
NOTES
FERC FORM NO.1 (ED.12-96)Page 276
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ACCUMULATED DEFERRED INCOME TAXES-OTHER (Account 283)(Continued)
3.Provide in the space below explanations for Page 276 and 277.Include amounts relating to insignificant items listed under Other.4.Use footnotes as required.
CHANGES DURINGYEAR ADJUSTMENTSAmountsDebitedAmountsCreditedDebits Credits Balance at LinetoAccount410.2 to Account 411.2 Account Amount Account Amount End of Year No.Credited Debited(e)(f)(g)(h)(i)(j)(k)
14,555 3
455,664 4
5
-928,137 6
7
182&186 83,586,046 182 &18 1,453,929 65,159,728 8
83,586,046 1,453,929 64,701,810 9
11
12
13
14
15
16
17
606,626 657,118 518,909 18
I606,626 657,118 83,586,046 1,453,929 65,220,719 19
20
504,248 643,082 42,626,638 1,206,475 53,959,234 21
102,378 14,037 40,959,408 247,454 11,261,484 22
23
NOTES (Continued)
FERC FORM NO.1 (ED.12-96)Page 277
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNCITEDATA
Schedule Page:276 Line No.:8 Column:b
Col B Col C Col D Col G Col H Col I Col J Col K
Oregon surcharge deferral (176,847)176,847
Ferc headwater benefits 152,423 36 152,460
Loss on reaguired debt (205,318)2,140,706 132,840 1,802,548
Amax coal purchase 2,035 9,890 11,925conservationprograms17,396,076 (1,899,732)1,935,351 13,560,993
PCA expense deferral (1,826,366)45,840,995 (3,174,043)47,188,672
PV startup costs 36,235 11,672 9,648 38,260
Post employment benefits 1,084,760 16,855 226,123 875,491Reorganizationcosts1,642,427 147,317 305,557 1,484,187
Unrealized gain mkt sec 216 322,351 182 531,929 209,578
FASB 109 accounting 82,341,695 182 3,885,285 186 922,000
FASB 109 xfer 282 79,378,410
Total other 100,447,120 46,444,586 (400,139)83,586,046 1,453,929 65,159,728
The FASB 109 transfer balance was transferred to account 282 from account 283 in 2000.
Schedule Page:276 Line No.:18 Column:b
Col B Col E Col F Col K
Advance coal royalties 569,401 605,925 657,118 518,208
Oregon non-op prop tax adj 701 701
Total Other 569,401 605,626 657,118 518,908
|FERC F()RWINCI.1 (ED.12-87)Page450
Name of Respondent This Re ort is:Date of Report Year of ReportidahoPowerCompany(1)An Original (Mo,Da,Yr)Dec.31,2000(2)A Resubmission 04/30/2001
Ol HER REGULATORY LIABILITIES (Account 254)
1.Reporting below the particulars (Details)called for concerning other regulatory liabilities which are created through the rate-makingactionsofregulatoryagencies(and not includable in other amounts)
2.For regulatory Liabilities being amortized show period of amortization in column (a).3.Minor items (5%of the Balance at End of Year for Account 254 or amounts less than $50,000,whichever is Less)may be groupedbyclasses.
Line Description and Purpose of DEBITS Balance atNo.Other Regulatory Liabilities Account Amount Credits End of YearCredited(a)(b)(c)(d)(e)
1
2 Idaho 1999 -NEEA (Nw energy efficiency act)232 1,185,081 5,446,207 4,418,9103
4
5 Idaho 1999 -Ag choices 182 17,132
6 229 240,392 6,040 12,8057
8 Boise Operation Center 184 31,970 189,1589
10
11 Unfunded Accumulated Deferred Income Tax 282 117,000
12 283 1,162,000 7,692,057 40,230,05713
14
15
16
17
18
19
20
21
22
23
24
25
I26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41 TOTAL 2.753,575 13,144,304 44,850,930
FERC FORM NO.1 (ED.12-94)Page 278
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
E .ECTRIC OPERATING REVENUES (Account 400)
1.Report below operating revenues for each prescribed account,and manufactured gas revenues in total.
2.Report number of customers,columns (f)and (g),on the basis of meters,in addition to the number of flat rate accounts;except that
where separate meter readings are added for billing purposes,one customer should be counted for each group of meters added.The
-average number of customers means the average of twelve figures at the close of each month.
3.If increases or decreases from previous year (columns (c),(e),and (g)),are not derived from previously reported figures,explain any
inconsistencies in a footnote.
Line Title of Account OPERATING REVENUES
No-Amount for Year Amount for Previous Year
(a)(b)(c)
1 Sales of Electricity se
2 (440)Residential Sales 225,336,243 213,547,286
3 (442)Commercial and Industrial Sales
4 Small (or Comm.)(See Instr.4)204,641,842 183,011,931
5 Large (or ind.)(See instr.4)133,171,352 117,365,705
6 (444)Public Street and Highway Lighting 2,207,136 2,223,530
7 (445)Other Sales to Public Authorities
8 (446)Sales to Railroads and Railways
9 (448)Interdepartmental Sales
10 TOTAL Sales to Ultimate Consumers 565,356,573 516,148,452
11 (447)Sales for Resale 229,985,643 119,784,606
12 TOTAL Sales of Electricity 795,342,216 635,933,058
13 (Less)(449.1)Provision for Rate Refunds -4,474,516 9,277,380
14 TOTAL Revenues Net of Prov.for Refunds 799,816,732 626,655,678
15 Other Operating Revenues
16 (450)Forfeited Discounts
17 (451)Miscellaneous Service Revenues 2,831,525 2,973,065
18 (453)Sales of Water and Water Power
19 (454)Rent from Electric Property 19,620,357 13,520,532
20 (455)Interdepartmental Rents
21 (456)Other Electric Revenues 13,393,150 15,186,892
22
23
24
25
26 TOTAL Other Operating Revenues 35,845,032 31,680,489
27 TOTAL Electric Operating Revenues 835,661,764 658,336,167
FERC FORM NO.1 (ED.12-96)Page 300
Name of Respondent This Re ort is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Idaho Power Company Dec.31,2000(2)A Resubmission 04/30/2001
ELECTRIC OPERATING REVENUES (Account 400)
4.Commercial and industrial Sales,Account 442,may be classified according to the basis of classification (Small or Commercial,andLargeorIndustrial)regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand.(See Account 442 of the Uniform System of Accounts.Explain basis of classification in a footnote.)5.See pages 108-109,Important Changes During Year,for important new territory added and important rate increase or decreases.6.For Lines 2,4,5,and 6,see Page 304 for amounts relating to unbilled revenue by accounts.
7.Include unmetered sales.Provide details of such Sales in a footnote.
MEGAWATT HOURS SOLD AVG.NO.CUSTOMERS PER MONTH LineAmountforYearAmountforPreviousYearNumberforYearNumberforPreviousYearNo.
(d)(e)(f)(g)
4,392,484 4,200,175 323,461 313,943 2
5,368,470 4,870,063 64,834 64,154 4
4,808,100 4,666,299 112 113 5
29,334 29,247 202 191 6
7
8
9
14,598,388 13,765,784 388,609 378,401 10
4,528,800 5,923,948 11
19,127,188 19,689,732 388,609 378,401 12
13
19,127,188 19,689,732 388,609 378,401 14
Line 12,column (b)includes $12,830,543 of unbilled revenues.
Line 12,column (d)includes 244,222 MWH relating to unbilled revenues
FERC FORM NO.1 (ED.12-96)Page 301
This Page Intentionally Left Blank
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Dec.31 2000IdahoPowerCompany(2)A Resubmission 04/30/2001 '
SALES OF ELECTRICITY BY RATE SCHEDULES
1.Report below for each rate schedule in effect during the year the MWH of electricity sold,revenue,average number of customer,average Kwh per
customer,and average revenue per Kwh,excluding date for Sales for Resale which is reported on Pages 310-311.
2.Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,"Page300-301.If the sales under any rate schedule are classified in more than one revenue account,List the rate schedule and sales data under eachapplicablerevenueaccountsubheading.
3.Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential
schedule and an off peak water heating schedule),the entries in column (d)for the special schedule should denote the duplication in number of reported
customers.
4.The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12
if all billings are made monthly).
5.For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
6.Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line Number and litle of Rate schedule MWh Sold Revenue Average Number KWh of Sales e ne er
No-(a)(b)(c)of Cusd)omers Per stomer
1 440 -Residential Sales:
2 01 -Residential 4,275,211 217,481,425 323,461 13,217 0.0509
3I 15 -Dusk to dawn lighting 2,674 684,462 0.2560
4 Residential Unbilled 114,599 7,170,356 0.0626
5 Total 440 4,392,484 225,336,243 323,461 13,580 0.0513
6
7 442-Commercial &Industrial Sales
8 07 -General service 285,690 17,813,006 32,580 8,769 0.0624
9 09 -General service 2,968,566 105,763,361 16,432 180,658 0.0356
10 10 -Large power winter service 99 8,739 4 24,750 0.0883
11 11 -General service 714 43,807 86 8,302 0.0614
12 12 -General service 17,818 667,419 107 166,523 0.0375
13 15 -Dusk to dawn lighting 3,970 980,209 0.2469
14 19 -Uniform rate contracts 2,206,762 60,741,315 108 20,432,981 0.0275
15 21 -Interruptible irrigation 656 13,795 4 164,000 0.0210
16 22 -Limited use Prairie Power 3 612 2 1,500 0.2040
17 24 -Irrigation Pumping 1,990,282 74,733,097 14,569 136,611 0.0375
18 40 -General service 14,525 698,475 910 15,962 0.0481
19 Commercial &Industrial 2,687,485 76,349,359 4 671,871,250 0.0284
20 Total 442 10,176,570 337,813,194 64,806 157,031 0.0332
21
22 444 -Public Street Lighting:
23 40 -General service 996 33,024 28 35,571 0.0332
24 41 -Street lighting 17,133 1,977,157 106 161,632 0.1154
25 42 -Traffic control lighting 11,989 251,179 68 176,309 0.0210
26 Public Lighting -784 -54,224 .0.0692
27 Total 444 29,334 2,207,136 202 145,218 0.0752
28
29
30
31
32
33
34
35
36
37
38
39
40
41 TOTAL Billed 14,354,166 552,526,030 C C 0.0385
42 Total Unbilled Rev.(See Instr.6)244,222 12,830,543 C C 0.0525
43 TOTAL 14,598,38E 565,356,573 C C 0.0387
FERC FORM NO.1 (ED.12-95)Page 304
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 4 7)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
No (Footnote Affiliations)Classifi-Schedule or Monthly Billing Avera e Avera e
cation Tariff Number Demand (MW)Monthly NC Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 City of Weiser RQ 32 8.970 8.879 7.839
2
3
4
5 American Electric Power SF WSPP NA NA NA
6 Alberta Power Pool SF -NA NA NA
7 Amoco Energy Trading Corp SF WSPP NA NA NA
8 City of Anaheim OS WSPP NA NA NA
9 City of Anaheim SF WSPP NA NA NA
10 Aquila Power Corp.SF WSPP NA NA NA
11 Arizona Electric Power Company OS WSPP NA NA NA
12 Arizona Public Service Co.SF WSPP NA NA NA
13 Arizona Public Service Co.SF WSPP NA NA NA
14 Avista Corp -WWP Div OS WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310
Name of Respondent This Re ort Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as allnon-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the natureoftheserviceinafootnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs underwhichservice,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter theaveragemonthlybillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and the averagemonthlycoincidentpeak(CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minuteintegration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,includingout-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled ontheLast-line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE L
Sold I Demand harges Energy Charges Other arges o a
(9)(h)(i)(j)(k)
51,371 356,302 1,027,423 570 1,384,295 1
2
3
4
1,201,698 72,981,594 72,981,594 5
21,190 5,974,672 5,974,672 6
30,800 1,504,700 1,504,700 7
4,307 138,023 138,023 8
247,168 11,812,681 11,812,681 9
968,362 58,153,921 -21,650 58,132,271 10
550 14,475 14,475 11
25 400 400 12
382,855 18,817,973 18,817,973 13
8,778 254,782 254,782 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 4<7)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)ss -SaŸih uu br DMeahryd
(Month N Deman Month y
CmP emand
(a)(b)(c)(d)(e)(f)
1 Avista Corp -WWP Div SF WSPP NA NA NA
2 Avista Corp -WWP Div Firm SF V6RS34 NA NA NA
3 Avista Corp -WWP Div Firm IF V6RS34 NA NA NA
4 Avista Energy,Inc OS WSPP NA NA NA
5 Avista Energy,Inc SF WSPP NA NA NA
6 City of Azusa SF WSPP NA NA NA
7 City of Azusa,Banning,Colton LF 84 NA NA NA
8 BC Hydro OS WSPP NA NA NA
9 BC Hydro SF WSPP NA NA NA
10 Basin Electric Power Cooperative SF V6RS41 NA NA NA
11 Benton County PUD SF WSPP NA NA NA
12 Bonneville Power Administration OS WSPP NA NA NA
13 Bonneville Power Administration SF WSPP NA NA NA
14 BP Energy Company SF WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.1
Name of Respondent This Report Is:Date of Report Year of Report(1)OX An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as allnon-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the natureoftheserviceinafootnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs underwhichservice,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter theaveragemonthlybillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and the averagemonthlycoincidentpeak(CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minuteintegration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,includingout-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled ontheLast-line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE LSoldDemandhargesEnergyChargesOtherarges
(g)(h)(i)(j)(k)
578,191 35,525,585 35,525,585 1
586,500 83,646,081 83,646,081 2
290,300 7,510,681 7,510,681 3
487 21,996 21,996 4
1,024,799 51,821,337 51,821,337 5
40,440 1,999,293 1,999,293 6
26,164 774,755 774,755 7
9,443 184,638 184,638 8
7,200 162,800 162,800 9
7,127 543,303 543,303 10
1,560 15,490 15,490 11
19,390 1,054,350 1,054,350 12
484,133 50,459,589 50,459,589 13
122,800 10,526,500 10,526,500 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.1
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this categonj for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
No.(Footnote Affiliations)Classifi-Schedule or Monthly Billing Avera e Avera e
cation Tariff Number Demand (MW)Monthly NC Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 City of Burbank SF WSPP NA NA NA
2 CA Dept Water Resc SF WSPP NA NA NA
3 Cal Independent System Operator SF -NA NA NA
4 Cal Independent System Operator SF -NA NA NA
5 California Power Exchange OS -NA NA NA
6 California Power Exchange SF -NA NA NA
7 California Power Exchange SF -NA NA NA
8 Calpine Power Services Co SF WSPP NA NA NA
9 Candela Energy Services SF WSPP NA NA NA
10 Cargill-Alliant,LLC SF WSPP NA NA NA
11 Chelan Co PUD SF WSPP NA NA NA
12 Citizens Power Sales SF WSPP NA NA NA
13 Clatskanie Co.PUD SF -NA NA NA
14 Coastal Merchant Energy L.P.OS WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.2
Name of Respondent This Report Is:Date of Report Year of Report(1)DXAn Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as allnon-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the natureoftheserviceinafootnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs underwhichservice,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter theaveragemonthlybillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and the averagemonthlycoincidentpeak(CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minuteintegration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,includingout-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled ontheLast-line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE Total ($)LineSoldDemandChargesIEnergyhargesOtherharges(h+i+j)No.
(g)(h)(i)(j)(k)
752 39,960 39,960 1
34,288 3,198,320 3,198,320 2
405,635 405,635 3
58,138 2,449,860 2,449,860 4
18,940 1,972,003 1,972,003 5
-9,988 -9,988 6
1,136,509 165,051,194 165,051,194 7
I400 101,200 101,200 8
26,975 4,174,352 4,174,352 9
130,685 6,145,510 6,145,510 10
9,185 1,066,460 1,066,460 11
399,950 12,147,949 12,147,949 12
34,836 809,589 809,589 13
400 38,000 38,000 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.2
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,000
SALES FOR RESALE (Account 4<7)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involvinga balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Sache Irenb
r
DMeorahr
d (Month yN Demant Month yœCmP emand
(a)(b)(c)(d)(e)(f)
1 Coastal Merchant Energy L.P.SF WSPP NA NA NA
2 Co RiverCommission of NV OS V6RS35 NA NA NA
3 Co RiverCommission of NV SF V6RS35 NA NA NA
4 Colorado Springs Utilitities SF WSPP NA NA NA
5 City of Colton SF WSPP NA NA NA
6 Constellation Power Source SF WSPP NA NA NA
7 Coral Power,LLC SF WSPP NA NA NA
8 Deseret Generation &Transmission SF WSPP NA NA NA
9 Duke Energy Trading &Marketing SF WSPP NA NA NA
10 Dynergy Power Marketing OS WSPP NA NA NA
11 Dynergy Power Marketing SF WSPP NA NA NA
12 Edison Mission Marketing &Trading SF WSPP NA NA NA
13 El Paso Merchant Energy,L.P.SF WSPP NA NA NA
14 Energy Services,Inc.IF V6RS4 NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.3
Name of Respondent This Re ort Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as allnon-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the natureoftheserviceinafootnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs underwhichservice,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter theaveragemonthlybillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and the averagemonthlycoincidentpeak(CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minuteintegration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,includingout-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled ontheLast-line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE
Sold Demand Charges Energy Charges Other Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
12,400 1,011,700 1,011,700 1
60 5,100 5,100 2
251,713 10,008,972 10,008,972 3
2,575 971,500 971,500 4
1,656 83,143 83,143 5
806,633 49,055,244 49,055,244 6
54,834 3,152,550 3,152,550 7
482 57,320 57,320 8
995,311 61,291,971 61,291,971 9
100 9,000 9,000 10
355,354 26,848,103 26,848,103 11
317,200 36,565,700 36,565,700 12
866,660 8,640 69,580,340 69,588,980 13
439,200 6,881,401 6,881,401 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.3
l Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 4:7)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
No (Footnote Affiliations)Classifi-Schedule or Monthly Billing Avera e AveracationTariffNumberDemand(MW)Monthly NC Demant Monthly CP emand
(a)(b)(c)(d)(e)(f)
1 Energy West Resources SF V6RS36 NA NA NA
2 Energy West Resources IF V6RS36 NA NA NA
3 Engage Energy US,L.P.SF WSPP NA NA NA
4 Enmax Energy Corporation SF WSPP NA NA NA
5 Enron Power Marketing,Inc.OS WSPP NA NA NA
6 Enron Power Marketing,Inc.SF WSPP NA NA NA
7 Eugene Water &Electric Board OS WSPP NA NA NA
8 """SF WSPP NA NA NA
9 Franklin County PUD SF WSPP NA NA NA
10 Glendale City of SF WSPP NA NA NA
11 Grant County PUD SF WSPP NA NA NA
12 Gray's Harbor Co PUD SF WSPP NA NA NA
13 lilinova Power Marketing Inc SF WSPP NA NA NA
14 Koch Energy Trading Inc.SF WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.4
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as allnon-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the natureoftheserviceinafootnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs underwhichservice,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter theaveragemonthlybillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and the averagemonthlycoincidentpeak(CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minuteintegration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,includingout-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled ontheLast-line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE L
Sold Demand harges Energy Charges Other arges o
(9)(h)(i)(j)(k)
27,470 648,490 648,490 1
17,468 333,005 333,005 2
39,000 1,401,200 1,401,200 3
1,105 140,125 140,125 4
430 39,450 39,450 5
4,202,770 327,946,823 327,946,823 6
355 8,640 8,640 7
23,606 1,410,008 1,410,008 8
1,080 9,970 9,970 9
1,515 244,755 244,755 10
194,024 3,578,587 3,578,587 11
68,050 1,565,884 1,565,884 12
55,157 1,467,176 1,467,176 13
77,800 4,482,100 4,482,100 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.4
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 4:7)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involvinga balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
fF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
I
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C on TSaÎlhe Irenb
r
DMeonahr
d (Month N Deman Month y CP emand
(a)(b)(c)(d)(e)(f)
1 Los Angeles Dept of Water &Power SF WSPP NA NA NA
2 """""SF WSPP NA NA NA
3 Mason County PUD #3 SF WSPP NA NA NA
4 City of McMinnville SF WSPP NA NA NA
5 Merchant Energy Group SF WSPP NA NA NA
6 Merrill Lynch Capital Services SF WSPP NA NA NA
7 Metropolitan Water District SF WSPP NA NA NA
8 MidAmerican Energy Corp SF WSPP NA NA NA
9 MlECO,Inc.SF WSPP NA NA NA
10 Montana Power Trading &Marketing SF WSPP NA NA NA
11 Morgan Stanley Capital Group SF WSPP NA NA NA
12 Nevada Power Company OS WSPP NA NA NA
13 """SF WSPP NA NA NA
14 N California Power Agency SF WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.5
Name of Respondent This Report is:Date of Report Year of Report(1)QX An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as allnon-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the natureoftheserviceinafootnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs underwhichservice,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter theaveragemonthlybillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and the averagemonthlycoincidentpeak(CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minuteintegration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,includingout-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled ontheLast-line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE
Sold Demand Charges Energy Charges Other Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
-100 -1,250.-1,250 1
15,622 1,352,597 1,352,597 2
120 810 810 3
1,083 40,732 40,732 4
103,575 3,018,429 3,018,429 5
94,600 10,801,600 10,801,600 6
3,550 149,250 149,250 7
175 1,487 1,487 8
168,000 5,503,040 5,503,040 9
37,363 5,485,421 5,485,421 10
102,600 8,388,870 8,388,870 11
4,696 328,704 328,704 12
444,235 29,580,445 -7,210 29,573,235 13
2,278 2,278 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.5
I Name of Respondent This Report Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)¯TSaih uu br DMeornahr
d (Month N Deman Month y CP emand
(a)(b)(c)(d)(e)(f)
1 N California Power Agency SF WSPP NA NA NA
2 Omaha Public Power District OS WSPP NA NA NA
3 Oregon Trail Electric Coop IF V6RS3 NA NA NA
4 """OS 134 NA NA NA
5 Pacific Northwest Gen Coop SF WSPP NA NA NA
6 Pacificorp Inc.OS WSPP NA NA NA
7 Pacificorp Inc.OS WSPP NA NA NA
8 PacifiCorp inc.SF WSPP NA NA NA
9 PacifiCorp Inc.SF WSPP NA NA NA
10 PacifiCorp Power Marketing inc SF WSPP NA NA NA
11 Pasadena City of SF WSPP NA NA NA
12 PECO Energy Co SF WSPP NA NA NA
13 PG&E Energy Trading SF WSPP NA NA NA
14 Pinnacle West Capital Corp SF WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.6
Name of Respondent This Re ort Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter theaveragemonthlybillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and the average
monthly coincident peak (CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximum
metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minute
integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,including
out-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)
the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled on
the Last -line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page
401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE
Sold Demand harges Energy Charges Other arges
(9)(h)(i)(j)(k)
800 77,600 77,600 1
100 1,500 1,500 2
75,696 1,503,973 1,503,973 3
8,784 172,632 172,632 4
32,625 843,310 843,310 5
250 5,771 5,771 6
7,065 217,260 217,260 7
-150 -3,950 -3,950 8
708,845 59,638,838 59,638,838 9
199,665 6,622,085 6,622,085 10
955 130,190 130,190 11
31,700 2,155,800 2,155,800 12
768,250 52,732,628 52,732,628 13
85,006 6,766,005 6,766,005 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.6
ÑBf Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involvinga balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
Classifi-Schedule or Monthly Billing Average I AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 PNM Energy Marketing OS WSPP NA NA NA
2 PNM Energy Marketing SF WSPP NA NA NA
3 Portland General Electric Co IF V6RS1 NA NA NA
4 """IF V6RS1 NA NA NA
5 """OS WSPP NA NA NA
6 """SF WSPP NA NA NA
7 Powerex Corp OS WSPP NA NA NA
8 Powerex Corp SF WSPP NA NA NA
9 PP&L Montana,LLC OS WSPP NA NA NA
10 PP&L Montana,LLC SF WSPP NA NA NA
11 Public Service of Colorado OS WSPP NA NA NA
12 """SF WSPP NA NA NA
13 Public Service of New Mexico OS WSPP NA NA NA
14 Public Service of New Mexico SF WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.7
Name of Respondent Tnis Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter
"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter the
average monthly billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the average
monthly coincident peak (CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximum
metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minute
integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.
Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,including
out-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)
the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled on
the Last -line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page
401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
IMegaWattHours REVENUE
Sold Demand harges 'Energy Charges i Other arges h+al($)ne
(9)(h)(i)(j)(k)
5,126 161,968 161,968 1
16,005 417,460 417,460 2
439,200 6,478,200 6,478,200 3
245,600 6,262,800 6,262,800 4
2,750 62,583 62,583 5
477,693 32,268,206 32,268,206 6
375 13,750 13,750 7
193,242 11,038,151 11,038,151 8
263 6,738 6,738 9
10,026 1,407,470 1,407,470 10
3,888 188,896 188.896 11
172,849 14,611,710 14,611,710 12
320 8,320 8,320 13
25 6,375 6,375 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.7
Name of Respondent This Re ort Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Sach ulrenb
r
DMeorahr
d (Month
a Deman MonthAymCPemand
(a)(b)(c)(d)(e)(f)
1 Public Service of New Mexico SF WSPP NA NA NA
2 Puget Sound Energy OS WSPP NA NA NA
3 Puget Sound Energy SF WSPP NA NA NA
4 Redding City of SF WSPP NA NA NA
5 Reliant Energy Services OS WSPP NA NA NA
6 Reliant Energy Services SF WSPP NA NA NA
7 City of Richland SF WSPP NA NA NA
8 City of Riverside OS WSPP NA NA NA
9 City of Riverside SF WSPP NA NA NA
10 Rocky Mountain Generation OS WSPP NA NA NA
11 Rocky Mountain Generation SF WSPP NA NA NA
12 Sacramento Mun Utility District OS WSPP NA NA NA
13 Sacramento Mun Utiltiy District SF WSPP NA NA NA
14 Salt River Project OS WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.8
Name of Respondent his Re ort Is:Date of Report Year of Report
I (1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter
"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter the
average monthly billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the average
monthly coincident peak (CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximum
metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minute
integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.
Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,including
out-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)
the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled on
the Last -line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page
401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE
Sold Demand Charges Energy Charges Other Charges Total ($)Line
($)($)($)(h+i+j)No.
(9)(h)(i)(j)(k)
327,385 34,605,866 34,605,866 1
5,855 246,255 246,255 2
399,744 30,873,008 30,873,008 3
1,400 260,000 260,000 4
800 76,000 76,000 5
126,000 16,255,400 16,255,400 6
3,595 93,470 93,470 7
802 23,540 23,540 8
53,603 3,874,664 3,874,664 9
200 25,000 25,000 10
795 29,080 29,080 11
2,400 455,200 455,200 12
46,700 4,190,690 4,190,690 13
1,026 34,449 34,449 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.8
Name of Respondent This Report is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 467)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
I
I
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
Classifi-Schedule or Monthly Billing Average [AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Deman Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 """SF WSPP NA NA NA
2 San Diego Gas &Electric SF WSPP NA NA NA
3 Seattle City of OS WSPP NA NA NA
4 """SF WSPP NA NA NA
5 Sempra Energy Trading Corp OS WSPP NA NA NA
6 Sempra Energy Trading Corp SF WSPP NA NA NA
7 Sierra Pacific Power Co LF 107 15.000 NA NA
8 Sierra Pacific Power Co OS WSPP NA NA NA
9 Sierra Pacific Power Co OS WSPP NA NA NA
10 Sierra Pacific Power Co SF WSPP NA NA NA
11 Sierra Pacific Power Co SF WSPP NA NA NA
12 Silicon Valley Power OS WSPP NA NA NA
13 Silicon Valley Power SF WSPP NA NA NA
14 Snohomish County PUD OS WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.9
Name of Respondent This Report is:Date of Report Year of Report(1)OX An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs under
which service,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter the
average monthly billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the average
monthly coincident peak (CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximum
metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minute
integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.
Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,including
out-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)
the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled on
the Last -line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page
401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE
Sold Demand harges Energy Charges Other arges Toh+al($)ne
(9)(h)(i)(j)(k)
88,126 3,909,978 3,909,978 1
113,400 11,051,630 11,051,630 2
81,600 3,738,100 3,738,100 3
1,093 53,417 53,417 4
68,194 2,010,763 2,010,763 5
861 64,490 64,490 6
420,800 29,754,160 29,754,160 7
1,025 140,350 140,350 8
315,199 17,447,157 17,447,157 9
51,966 3,518,664 3,518,664 10
24,510 2,662,015 2,662,015 11
51,826 7,161,215 7,161,215 12
136,452 361,500 3,650,091 4,011,591 13
78,897 6,621,436 6,621,436 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.10
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s SaÎihe Irenb
r
DMeahr
d (Month N Demar MonthAywCmPemand
(a)(b)(c)(d)(e)(f)
1 Tucson Electric Power Co SF WSPP NA NA NA
2 Tucson Electric Power Co SF WSPP NA NA NA
3 Utah Assoc Mun Power System LF 75 52.500 NA NA
4 Utah Assoc Mun Power System OS WSPP NA NA NA
5 Utah Assoc Mun Power System SF WSPP NA NA NA
6 Utah Municipal Power Agency SF WSPP NA NA NA
7 Utah Municipal Power Agency OS V6RS18 NA NA NA
8 Utah Municipal Power Agency SF V6RS18 NA NA NA
9 UtiliCorp United,Inc.OS WSPP NA NA NA
10 UtiliCorp United,Inc.SF WSPP NA NA NA
11 Vanalco,Inc.SF V6RS4 NA NA NA
12 Vernon City of SF WSPP NA NA NA
13 Washington City of LF 74 9.083 NA NA
14 West Kootenay Power,Ltd SF WSPP NA NA NA
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.11
Name of Respondent This Re ort Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs underwhichservice,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter the
average monthly billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the average
monthly coincident peak (CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximum
metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minute
integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.
Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,including
out-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)
the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled on
the Last -line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page
401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page
401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE
Sold Demand harges Energy Charges Other arges h+al($)n
(9)(h)(i)(j)(k)
150 1
55,045 2,173,137 2,173,137 2
386,946 3,307,500 10,002,043 13,309,543 3
24,671 774,118 774,118 4
-720 13,200 13,200 5
358,262 21,087,296 21,087,296 6
1,526 44,356 44,356 7
25,321 1,327,065 1,327,065 8
210 7,140 7,140 9
105 1,759 1,759 10
219,550 11,751,003 11,751,003 11
114,777 8,717,018 8,717,018 12
49,655 572,250 726,205 1,298,455 13
2,138 28,596 28,596 14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.11
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 4:7)
1.Report all sales for resale (i.e.,sales to purchasers other than ultimate consumers)transacted on a settlement basis other than
power exchanges during the year.Do not report exchanges of electricity (i.e.,transactions involving a balancing of debits and credits
for energy,capacity,etc.)and any settlements for imbalanced exchanges on this schedule.Power exchanges must be reported on the
Purchased Power schedule (Page 326-327).
2.Enter the name of the purchaser in column (a).Do note abbreviate or truncate the name or use acronyms.Explain in a footnote any
ownership interest or affiliation the respondent has with the purchaser.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projected load for this service in its system resource planning).In addition,the reliability of requirements service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for tong-term service."Long-term"means five years or Longer and "firm"means that service cannot be interrupted for economic
reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency energy
from third parties to maintain deliveries of LF service).This category should not be used for Long-term firm service which meets the
definition of RQ service.For all transactions identified as LF,provide in a footnote the termination date of the contract defined as the
earliest date that either buyer or setter can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service except that "intermediate-term"means longer than one year but Less
than five years.
SF -for short-term firm service.Use this category for all firm services where the duration of each period of commitment for service is
one year or less.
LU -for Long-term service from a designated generating unit."Long-term"means five years or Longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service except that "intermediate-term"means
Longer than one year but Less than five years.
I
Line Name of Company or Public Authority Statistical FERC Rate Avera e Actual Demand (MW)
No.(Footnote Affiliations)C s -Sache
u br
DMeahr
d (Month N Deman<Month yœCP emand
(a)(b)(c)(d)(e)(f)
1 Western Area Power Administration SF WSPP NA NA NA
2 Western Resources,Inc.OS WSPP NA NA NA
3 Williams Energy Marketing &Trading OS WSPP NA NA NA
4 """SF WSPP NA NA NA
5 Less Non-Operating Sales
6 Less write off
7
8 OS Sales:Non-firm sales
9
10
11
12
13
14
Subtotal RQ 0 0 0
Subtotal non-RQ 0 0 0
Total 0 0 0
FERC FORM NO.1 (ED.12-90)Page 310.12
Name of Respondent This Report is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SALES FOR RESALE (Account 447)(Continued)
OS -for other service.use this category only for those services which cannot be placed in the above-defined categories,such as allnon-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote.
AD -for Out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.Group requirements RQ sales together and report them starting at line number one.After listing all RQ sales,enter "Subtotal -RQ"
in column (a).The remaining sales may then be listed in any order.Enter "Subtotal-Non-RQ"in column (a)after this Listing.Enter"Total"in column (a)as the Last Line of the schedule.Report subtotals and total for columns (9)through (k)
5.In Column (c),identify the FERC Rate Schedule or Tariff Number.On separate Lines,List all FERC rate schedules or tariffs underwhichservice,as identified in column (b),is provided.
6.For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer)basis,enter theaveragemonthlybillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and the averagemonthlycoincidentpeak(CP)
demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly NCP demand is the maximum
metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand during the hour (60-minute
integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
7.Report in column (g)the megawatt hours shown on bills rendered to the purchaser.
8.Report demand charges in column (h),energy charges in column (i),and the total of any other types of charges,includingout-of-period adjustments,in column (j).Explain in a footnote all components of the amount shown in column (j).Report in column (k)the total charge shown on bills rendered to the purchaser.
9.The data in column (g)through (k)must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4),and then totaled ontheLast-line of the schedule.The "Subtotal -RQ"amount in column (g)must be reported as Requirements Sales For Resale on Page
401,line 23.The "Subtotal -Non-RQ"amount in column (g)must be reported as Non-Requirements Sales For Resale on Page401,iine 24.
10.Footnote entries as required and provide explanations following all required data.
MegaWatt Hours REVENUE
Sold Demand harges Energy Charges Other arges o a
(g)(h)(i)(j)(k)
236,410 13,386,267 13,386,267 1
630 42,210 42,210 2
50 2,000 2,000 3
756,630 41,826,569 41,826,569 4
-23,188,436 -1,687,096,893 -1,687,096,893 5
-49,560 -49,560 6
7
|8
9
10
11
12
13
14
51,371 356,302 1,027,423 570 1,384,295
4,477,429 4,643,640 223,986,568 -28,860 228,601,348
4,528,800 4,999,942 225,013,991 -28,290 229,985,643
FERC FORM NO.1 (ED.12-90)Page 311.12
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTE DATA
Schedule Page:310 Line No.:1 Column:j
Other charges represent a customer charge authorized by Supplement No.7 to rate schedule
FERC No.42.
Schedule Page:310 Line No.:8 Column:b
Represents non-firm sales.
Schedule Page:310 Line No.:10 Column:jLiquidatedDamages.
Schedule Page:310 Line No.:11 Column:b
Represents non-firm sales.
Schedule Page:310 Line No.:12 Column:a
1999 Corrections .
Schedule Page:310 Line No.:14 Column:b
Represents non-firm sales.
Schedule Page:310.1 Line No.:4 Column:b
Represents non-firm sales.
Schedule Page:310.1 Line No.:6 Column:a
Contract expires 9/30/09.
Schedule Page:310.1 Line No.:8 Column:b
Represents non-firm sales.
Schedule Page:310.1 Line No.:12 Column:b
Represents non-firm sales.
Schedule Page:310.2 Line No.:3 Column:a
1999 Correction.
Schedule Page:310.2 Line No.:5 Column:b
Represents non-firm sales.
Schedule Page:310.2 Line No.:6 Column:a
1999 Correction.
Schedule Page:310.2 Line No.:14 Column:b
Represents non-firm sales.
Schedule Page:310.3 Line No.:2 Column:b
Represents non-firm sales.
Schedule Page:310.3 Line No.:10 Column:b
Represents non-firm sales.
Schedule Page:310.4 Line No.:5 Column:b
Represents non-firm sales.
Schedule Page:310.4 Line No.:7 Column:b
Represents non-firm sales.
Schedule Page:310.5 Line No.:12 Column:b
Represents non-firm sales.
Schedule Page:310.5 Line No.:13 Column:j
1998 contract shortfall charges.
Schedule Page:310.6 Line No.:2 Column:b
Represents non-firm sales.
Schedule Page:310.6 Line No.:3 Column:a
contract expires 9/30/01
Schedule Page:310.6 Line No.:4 Column:b
FERC FORM NO.1 (ED.12-87)Page 450
NameofRespondent ThisRepodis:DateofRepod YearofRepod
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTEDATA
Represents non-firm sales.
Schedule Page:310.6 Line No.:6 Column:a
1999 Correction.
Schedule Page:310.6 Line No.:6 Column:b
Represents non-firm sales.
Schedule Page:310.6 Line No.:7 Column:b
Represents non-firm sales.
Schedule Page:310.6 Line No.:8 Column:a
1999 Correction.
Schedule Page:310.7 Line No.:1 Column:b
Represents non-firm sales.
Schedule Page:310.7 Line No.:5 Column:b
Represents non-firms sales.
Schedule Page:310.7 Line No.:7 Column:b
Represents non-firm sales.
Schedule Page:310.7 Line No.:9 Column:b
Represents non-firm sales.
Schedule Page:310.7 Line No.:11 Column:b
Represents non-firm sales.
Schedule Page:310.7 Line No.:13 Column:b
Represents non-firm sales.
Schedule Page:310.8 Line No.:2 Column:b
Represents non-firm sales.
Schedule Page:310.8 Line No.:5 Column:b
Represents non-firm sales.
Schedule Page:310.8 Line No.:8 Column:b
Represents non-firm sales.
Schedule Page:310.8 Line No.:10 Column:b
Represents non-firm sales.
Schedule Page:310.8 Line No.:12 Column:b
Represents non-firm sales.
Schedule Page:310.8 Line No.:14 Column:b
Represents non-firm sales.
Schedule Page:310.9 Line No.:3 Column:b
Represents non-firm sales.
Schedule Page:310.9 Line No.:5 Column:b
Represents non-firm sales.
Schedule Page:310.9 Line No.:8 Column:a
1999 Corrections.
Schedule Page:310.9 Line No.:8 Column:b
Represents non-firm sales.
Schedule Page:310.9 Line No.:9 Column:b
Represents non-firm sales.
Schedule Page:310.9 Line No.:10 Column:a
1999 Corrections.
Schedule Page:310.9 Line No.:12 Column:b
Represents non-firm sales.
FERC FORM NO.1 (ED.12-87)Page 450.1
This Page Intentionally Left Blank
NanasofRespondent ThisRepodis:DateofReport YearofReport
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTEDATA
Schedule Page:310.9 Line No.:14 Column:b
Represents non-firm sales.
Schedule Page:310.10 Line No.:4 Column:b
Represents non-firm sales.
Schedule Page:310.10 Line No.:8 Column:b
Represents non-firm sales.
Schedule Page:310.10 Line No.:11 Column:b
Represents non-firm sales.
Schedule Page:310.10 Line No.:14 Column:b
Represents non-firm sales.
Schedule Page:310.11 Line No.:4 Column:a
Contract expires 12/31/03.
Schedule Page:310.11 Line No.:4 Column:b
Represents non-firm sales.
Schedule Page:310.11 Line No.:7 Column:b
Represents non-firm sales.
Schedule Page:310.11 Line No.:9 Column:b
Represents non-firm sales.
Schedule Page:310.11 Line No.:13 Column:a
Contract expires 6/30/02
Schedule Page:310.12 Line No.:2 Column:b
Represents non-firm sales.
Schedule Page:310.12 Line No.:3 Column:b
Represents non-firm sales.
Schedule Page:310.12 Line No.:5 Column:a
Sales identified as non-operating are properly accounted for in account 421
FERC FORM NO.1 (ED.12-87)Page 450.2
Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Line Account Amount for Amount forCurrentYearPreviousYearNo.(a)(b)(c)
1 1.POWER PRODUCTION EXPENSES
2 A.Steam Power Generation Ik at .
3 Operation 75*£
.
4 (500)Operation Supervision and Engineering 1,914,776 2,256,951
5 (501)Fuel 93,934,790 86,607,880|
6 (502)Steam Expenses 5,872,113 4,587,395
7 (503)Steam from Other Sources
8 (Less)(504)Steam Transferred-Cr.
9 (505)Electric Expenses 1,359,746 1,310,094
10 (506)Miscellaneous Steam Power Expenses 11,188,983 12,456,701
11 (507)Rents 588,925 591,012
12 (509)Allowances
13 TOTAL Operation (Enter Total of Lines 4 thru 12)114,859,333 107,810,033
14 Maintenance
15 (510)Maintenance Supervision and Engineering 1,641,653 1,287,926
16 (511)Maintenance of Structures 297,833 150,372
17 (512)Maintenance of Boiler Plant 6,759,142 7,467,058
18 (513)Maintenance of Electric Plant 1,816,152 2,693,103
19 (514)Maintenance of Miscellaneous Steam Plant 2,758,799 1,353,146
20 TOTAL Maintenance (Enter Total of Lines 15 thru 19)13,273,579 12,951,605
21 TOTAL Power Production Expenses-Steam Power (Entr Tot lines 13 &20)128,132,912 120,761,638
22 B.Nuclear Power Generation ..I".
23 Operation ad
24 (517)Operation Supervision and Engineering
25 (518)Fuel
26 (519)Coolants and Water
27 (520)Steam Expenses
28 (521)Steam from Other Sources
29 (Less)(522)Steam Transferred-Cr.
30 (523)Electric Expenses
31 (524)Miscellaneous Nuclear Power Expenses
32 (525)Rents
33 TOTAL Operation (Enter Total of lines 24 thru 32)
34 Maintenance
35 (528)Maintenance Supervision and Engineering
36 (529)Maintenance of Structures
37 (530)Maintenance of Reactor Plant Equipment
38 (531)Maintenance of Electric Plant
39 (532)Maintenance of MisœIlaneous Nuclear Plant
40 TOTAL Maintenance (Enter Total of lines 35 thru 39)
41 TOTAL Power Production Expenses-Nuc.Power (Entr tot lines 33 &40)
42 C.Hydraulic Power Generation r 'e
43 Operation
44 (535)Operation Supervision and Engineering 3,270,213 3,102,126
45 (536)Water for Power 3,842,505 4,843,732
46 (537)Hydraulic Expenses 4,268,910 3,965,025
47 (538)Electric Expenses 1,007,573 1,011,206
48 (539)Miscellaneous Hydraulic Power Generation Expenses 1,677,136 1,762,671
49 (540)Rents 351,057 347,915
50 TOTAL Operation (Enter Total of Lines 44 thru 49)14,417,394 15,032,675
FERC FORM NO.1 (ED.12-93)Page 320
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)000idahoPowerCompanyDec.31,2(2)A Resubmission 04/30/2001
ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)
If the amount for previous year is not derived from previously reported figures,e::plain in footnote.
Line Account Amount for Amount forCurrentYearPreviousYearNo(a)(b)(c)
51 C.Hydraulic Power Generation (Continued)&¶JPJ &¾fi
52 Maintenance
53 (541)Mainentance Supervision and Engineering 945,982 767,907
54 (542)Maintenance of Structures 1,146,517 1,107,663
55 (543)Maintenance of Reservoirs,Dams,and Watenways 756,812 738,459
56 (544)Maintenance of Electric Plant 2,571,341 2,970,563
57 (545)Maintenance of Miscellaneous Hydraulic Plant 2,199,123 2,127,813
58 TOTAL Maintenance (Enter Total of lines 53 thru 57)7,619,775 7,712,405
59 TOTAL Power Production Expenses-Hydraulic Power (tot of lines 50 &58)22,037,169 22,745,080
60 D.Other Power Generation $lfi
61 Operation
62 (546)Operation Supervision and Engineering 5,456
63 (547)Fuel 279,914 8,845
64 (548)Generation Expenses 5,767 4,699
65 (549)Miscellaneous Other Power Generation Expenses 3,030 988
66 (550)Rents
67 TOTAL Operation (Enter Total of lines 62 thru 66)288,711 19,988
68 Maintenance ÑF Á
69 (551)Maintenance Supervision and Engineering 974
70 (552)Maintenance of Structures 1,418 142
71 (553)Maintenance of Generating and Electric Plant 94,079 19,699
72 (554)Maintenance of Miscellaneous Other Power Generation Plant 111
73 TOTAL Maintenance (Enter Total of lines 69 thru 72)95,497 20,926
74 TOTAL Power Production Expenses-Other Power (Enter Tot of 67 &73)384,208 40,914
75 E.Other Power Supply Expenses A <
76 (555)Purchased Power 398,648,515 106,343,659
77 (556)System Control and Load Dispatching 1,305,897 1,326,755
78 (557)Other Expenses -120,688,043 189,725
79 TOTAL Other Power Supply Exp (Enter Total of lines 76 thru 78)279,266,369 107,860,139
80 TOTAL Power Production Expenses (Total of lines 21,41,59,74 &79)429,820,658,251,407,771
81 2.TRANSMISSION EXPENSES
82 Operation
83 (560)Operation Supervision and Engineering 1,845,060 2,218,682
84 (561)Load Dispatching 2,102,551 1,965,859
85 (562)Station Expenses 1,325,032 149,200
86 (563)Overhead Lines Expenses 575,998 299,723
87 (564)Underground Lines Expenses
88 (565)Transmission of Electricity by Others 214,729 2,759,042
89 (566)Miscellaneous Transmission Expenses 192,398 828,332
90 (567)Rents 1,450,839 1,257,998
91 TOTAL Operation (Enter Total of lines 83 thru 90)7,706,607 9 478 836
92 Maintenance
93 (568)Maintenance Supervision and Engineering 486,512 333,304
94 (569)Maintenance of Structures 32
95 (570)Maintenance of Station Equipment 2,722,766 2,099,423
96 (571)Maintenance of Overhead Lines 1,980,052 1,865,398
97 (572)Maintenance of Underground Lines
98 (573)Maintenance of Miscellaneous Transmission Plant 77
99 TOTAL Maintenance (Enter Total of lines 93 thru 98)5,189,330 4,298,234
100 TOTAL Transmission Expenses (Enter Total of lines 91 and 99)12,895,937 13,777,070
101 3.DISTRIBUTION EXPENSES AÑÅK A =1
102 Operation yf¾¶à¾¢
103 (580)Operation Supervision and Engineering 3,813,807 4,686,239
FERC FORM NO.1 (ED.12-93)Page 321
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Line Account Amount for Amount forCurrentYearPreviousYearNo(a)(b)(c)
104 3.DISTRIBUTION Expenses (Continued)BWägg R
105 (581)Load Dispatching 2,564,464 2,381,570
106 (582)Station Expenses 1,581,950 2,665,104
107 (583)Overhead Line Expenses 3,707,321 2,930,567
108 (584)Underground Line Expenses 2,668,978 2,017,240
109 (585)Street Lighting and Signal System Expenses 665,475 229,617
110 (586)Meter Expenses 3,662,088 2,865,455
111 (587)Customer installations Expenses 521,230 790,684
112 (588)Miscellaneous Expenses 4,309,779 7,176,448
113 (589)Rents 134,011 141,192
114 TOTAL Operation (Enter Total of lines 103 thru 113)23,629,103 25,884,116
115 Maintenance gg
116 (590)Maintenance Supervision and Engineering 93,893 136,808
117 (591)Maintenance of Structures 8,385 9,784
118 (592)Maintenance of Station Equipment 3,051,094 1,711,823
119 (593)Maintenance of Overhead Lines 10,136,819 7,087,380
120 (594)Maintenance of Underground Lines 1,521,154 1,294,170
121 (595)Maintenance of Line Transformers 2,185,435 2,666,617
122 (596)Maintenance of Street Lighting and Signal Systems 75,437 303,715
123 (597)Maintenance of Meters 1,738,745 1,846,391
124 (598)Maintenance of Miscellaneous Distribution Plant 274,492 106,705
125 TOTAL Maintenance (Enter Total of lines 116 thru 124)19,085,454 15,163,393
126 TOTAL Distribution Exp (Enter Total of lines 114 and 125)42,714,557 41,047,509
127 4.CUSTOMER ACCOUNTS EXPENSES
128 Operation Mi Ù
129 (901)Supervision 466,014 149,531
130 (902)Meter Reading Expenses 4,697,787 4,311,252
131 (903)Customer Records and Collection Expenses 6,551,273 7,053,411
132 (904)Uncollectible Accounts 1,658,023 1,547,317
133 (905)Miscellaneous Customer Accounts Expenses 6,849 141,872
134 TOTAL Customer Accounts Expenses (Total of lines 129 thru 133)13,379,946 13,203,383
135 5.CUSTOMER SERVICE AND INFORMATIONAL EXPENSES BG
136 Operation
137 (907)Supervision 92,332 35,706
138 (908)Customer Assistance Expenses 8,094,767 6,501,907
139 (909)Informational and instructional Expenses 140,007 83,783
140 (910)Miscellaneous Customer Service and Informational Expenses 539,328 714,199
141 TOTAL Cust.Service and Information.Exp.(Total lines 137 thru 140)8,866,434 7,335,595
142 6.SALES EXPENSES
143 Operation
144 (911)Supervision
145 (912)Demonstrating and Selling Expenses
146 (913)Advertising Expenses
147 (916)Miscellaneous Sales Expenses
148 TOTAL Sales Expenses (Enter Total of lines 144 thru 147)
149 7.ADMINISTRATIVE AND GENERAL EXPENSES
150 Operation
151 (920)Administrative and General Salaries 34,636,895 27,851,593
152 (921)Office Supplies and Expenses 18,073,014 15,275,823
153 (Less)(922)Administrative Expenses Transferred-Credit 20,549,566 18,312,458
FERC FORM NO.1 (ED.12-93)Page 322
Name of Respondent This Re ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Idaho Power Company Dec.31,2000(2)A Resubmission 04/30/2001
ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)
If the amount for previous year is not derived from previously reported figures,explain in footnote.
Line i Account Amount for Amount for
I Current Year Previous YearNo(a)(b)(c)
154 7.ADMINISTRATIVE AND GENERAL EXPENSES (Continued)4¾
155 (923)Outside Services Employed 4,395,508 5,589,526
156 (924)Property Insurance 1,689,591 1,498,565
157 (925)Injuries and Damages 3,454,966 4,129,519
158 (926)Employee Pensions and Benefits 7,723,227 15,343,399
159 (927)Franchise Requirements 2,389 1,595
160 (928)Regulatory Commission Expenses 4,260,439 3,499,450
161 (929)(Less)Duplicate Charges-Cr.
162 (930.1)General Advertising Expenses 643,830 649,276
163 (930.2)Miscellaneous General Expenses 1,817,408 2,068,746
164 (931)Rents 37,308 39,069
165 TOTAL Operation (Enter Total of lines 151 thru 164)56,185,009 57,634,103
166 Maintenance GTWR ÑË
167 (935)Maintenance of General Plant 1,709,412 1,921,109
168 TOTAL Admin &General Expenses (Total of lines 165 thru 167)57,894,421 59,555,212
169 TOTAL Elec Op and Maint Expn (Tot 80,100,126,134,141,148,168)565,571,953 386,326,540
NUMBER OF ELECTRIC DEPARTMENT EMPLOYEES
1.The data on number of employees should be reported construction employees in a footnote.for the payroll period ending nearest to October 31,or any 3.The number of employees assignable to the electricpayrollperiodending60daysbeforeorafterOctober31.department from joint functions of combination utilities may
2.If the respondent's payroll for the reporting period be determined by estimate,on the basis of employee equi-
includes any special construction personnel,include such valents.Show the estimated number of equivalent employees
employes on line 3,and show the number of such special attributed to the electric department from joint functions.
1.Payroll Period Ended (Date)12/29/2000
2.Total Regular Full-Time Employees 1,695
3.Total Part-Time and Temporary Employees 18
4.Total Employees 1,713
FERC FORM NO.1 (ED.12-93)Page 323
Name of Respondent This Report Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
PURCHASED POWER (Account 555)(including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
Classifi-Schedule or Monthly Billing Average I AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 COGENERATION &SMALL POWER
2 Willis and Betty Deveny LU -NA NA NA
3 James B Howell LU -NA NA NA
4 Tamarack Energy Partnership LU -4.92Mw Unavl Unavl
5 Emmett Power Company LU -NA NA NA
6 Mitchell Butte LU -NA NA NA
7 Owyhee Dam LU -NA NA NA
8 Tunnel #1 LU -NA NA NA
9 Reynolds Irrigation District LU -NA NA NA
10 Clifton E Jenson LU -.05Mw Unavl Unavl
11 Snake River Pottery LU -NA NA NA
12 White Water Ranch LU -NA NA NA
13 John R LeMoyne LU -NA NA NA
14 David R Snedigar LU -NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326
Name of Respondent This Re ort Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU RCHA ÞÖWER(Account 555)(Continued)ncluding power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriatedesignationforthecontract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demandduringthehour(60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthoursofpowerexchangesreceivedanddelivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (l).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlementamountforthenetreceiptofenergy.If more energy was delivered than received,enter a negative amount.If the settlement amount (l)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES 'COST/SETTLEMENT OF POWERMP0aWattHonrs
I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
90C 58,391 58,391 2
3,837 240,246 240,245 3
38,19E 1,576,498 1,380,462 2,956,961 4
78,507 5,650,546 5,650,546 5
7,50E 522,78E 522,789 6
25,66C 1,595,68E 1,595,689 7
16,637 1,603,282 1,603,282 8
1,591 109,296 109,298 9
29E 17,500 7,296 24,795 10
44E 27,84E 27,848 11
755 47,054 47,054 12
62C 33,465 33,465 13
1,561 101,062 101,062 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,816
FERC FORM NO.1 (ED.12-90)Page 327
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 565)(including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Mud Creek Hydro LU -NA NA NA
2 Rim View Trout Company OS -NA NA NA
3 Curry Cattle Company LU .084Mw Unavl Unavl
4 Branchflower Company LU -NA NA NA
5 Big Wood Canal Company LU -NA NA NA
6 Jim Knight LU -NA NA NA
7 Sagebrush LU -NA NA NA
8 Fisheries Development OS -NA NA NA
9 Shoshone LU -NA NA NA
10 Shoshone #2 LU -NA NA NA
11 Rock Creek Joint Venture LU -1.732Mw Unavi Unavl
12 Box Canyon LU -NA NA NA
13 Briggs Creek LU -NA NA NA
14 JD McCollum LU -NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.1
Name of Respondent This Report Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU RCHASEDÞQWÊlR(Account 555)(Continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriatedesignationforthecontract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enter
the monthly average billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the
average monthly coincident peak (CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demandduringthehour(60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (I).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlementamountforthenetreceiptofenergy.If more energy was delivered than received,enter a negative amount.If the settlement amount (I)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COST/SETTLEMENT OF POWERl\degaWett Hours I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges I Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(l)(m)
45E 28,014 28,014 1
51 15,681 15,681 2
685 26,796 16,892 43,689 3
1,077 69,742 69,742'4
46E 28,11E 28,116 5
1,181 78,216 78,216 6
1,506 100,32E 100,328 7
522 79,572 79,573 8
2,39E 180,895 180,895 9
2,646 165,472 165,472 10
13,233 552,508 326,187 878,695 11
1,54E 95,23E 95,238 12
3,785 237,374 237,374 13
904 62,677 62,677 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,81€
FERC FORM NO.1 (ED.12-90)Page 327.1
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 565)(Includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term sentice from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-definedcategories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
Classifi-Schedule or i Monthly Billing Average |AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demanti Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Zions Credit Corp/Mud Creek LU -NA NA NA
2 Vernon Ravenscroft LU -.488Mw Unavl Unavl
3 William Arkoosh LU -NA NA NA
4 Clear Springs Food Inc.LU -NA NA NA
5 Koyle Hydro Inc.LU -NA NA NA
6 Kasel &Witherspoon LU -NA NA NA
7 Lateral 10 Ventures LU -NA NA NA
8 Crystal Springs Hydro LU -NA Unavl Unavl
9 Pigeon Cove Power LU -1.389Mw NA NA
10 Notch Butte Hydro Co.LU -NA NA NA
11 Barber Dam LU -NA NA NA
12 Rock Creek 2 LU -NA NA NA
13 Dietrich Drop LU -NA NA NA
14 Lowline #2 LU -NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.2
Name of Respondent This Report Is:Date of Report Year of Report(1)QX An Original (Mo,Da,Yr)2000ldahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU RCHA POWER(Account 555)(Continued)ncluding power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriatedesignationforthecontract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand
during the hour (60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthoursofpowerexchangesreceivedanddelivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (l).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount forthe net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (l)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COST/SETTLElv ENT OF POWERMegaWattHours I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
1,59C 109,352 109,353 1
3,132 155,672 78,751 234,423 2
4,611 314,14E 314,148 3
3,652 294,596 294,595 4
4,991 335,55E 335,556 5
4,77E 349,305 349,305 6
9,35C 588,307 588,307 7
9,70E 599,235 599,235 8
9,145 486,150 195,975 682,125 9
4,164 280,941 280,941 10
13,62E 604,577 604,577 11
9,091 419,051 419,051 12
17,275 838,73C 838,730 13
10,407 488,356 488,356 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,816
FERC FORM NO.1 (ED.12-90)Page 327.2
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De Tiand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demand Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Cedar Draw/Little Mac Power LU -NA NA NA
2 South Forks Joint Venture LU -NA NA NA
3 Little Wood River Irrigation District LU -NA NA NA
4 Rancher's Irrigation District LU -NA NA NA
5 Faulkner Brothers Hydro LU -NA NA NA
6 Magic Reservoir Hydro LU -NA NA NA
7 Bypass Limited LU -NA NA NA
8 SE Hazelton A LP LU -NA NA NA
9 Jerry L McMillan OS -NA NA NA
10 Lemhi HydroPower Company LU -NA NA NA
11 JR Simplot LU -NA NA NA
12 Blind Canyon Hydro LU -NA NA NA
13 City of Boise LU -NA NA NA
14 City of Hailey LU -NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.3
Name of Respondent This Report is:Date of Report Year of Report(1)QX An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU RCHA PÖWER(Account 555)(Continued)ncluding power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriate
designation for the contract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,as
identified in column (b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enter
the monthly average billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the
average monthly coincident peak (CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly
NCP demand is the maximum metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand
during the hour (60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)
must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,including
out-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (l).Report in column (m)
the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (l)
include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by the
agreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
I POWER EXCHANGES I COST/SETTLEN ENT OF POWERMegaWattHolireI I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+1)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
6,274 372,702 372,703 1
30,641 2,045,466 2,045,465 2
4,97E 325,08E 325,088 3
3,097 189,98E 189,988 4
3,185 224,96E 224,969 5
19,49E 928,59E 928,598 6
28,847 1,383,41E 1,383,419 7
24,79E 1,134,021 1,134,021 8
134 10,494 10,494 9
1,06E 73,38E 73,389 10
83,56E 4,819,364 4,819,364 11
6,65E 393,161 393,161 12
1,171 65,131 65,131 13
301 19,27E 19,276 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,81E
FERC FORM NO.1 (ED.12-90)Page 327.3
Name of Respondent This Report Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 City of Pocatello LU -NA NA NA
2 Marysville Hydro Partners LU -NA NA NA
3 Wilson Power Company LU -NA NA NA
4 Hazelton Power Company LU -NA NA NA
5 Pristine Springs LU -NA NA NA
6 Vaagen Brothers Lumber Inc.LU -NA NA NA
7 Horseshoe Bend Hydro LU -NA NA NA
8 Contractors Power Group Inc.LU -NA NA NA
9 Rupert Cogeneration Partners LU -NA NA NA
10 Glenns Ferry Cogeneration Partners LU -NA NA NA
11 Tasco OS -NA NA NA
12 Energy differences NA NA NA
13
14
Total
FERC FORM NO.1 (ED.12-90)Page 326.4
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU RCHA POWER(Account 555)(Öontinued)uding power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriate
designation for the contract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand
during the hour (60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (I).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (!)
include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by the
agreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
I POWER EXCHANGES I COST/SETTLEMENT OF POWEROBWattHaitreI,l.ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
1,341 91,156 91,156 1
45,542 2,655,164 2,655,164 2
27,72E 1,797,705 1,797,705 3
24,18C 1,568,001 1,568,001 4
1,00C 37,976 37,976 5
26,60E 1,529,907 1,529,907 6
42,67E 2,749,805 2,749,805 7
5,391 339,327 339,327 8
82,592 4,994,53C 4,994,530 9
78,523 4,761,794 4,761,794 10
12 1,175 1,175 11
-1,072 12
13
14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,81E
FERC FORM NO.1 (ED.12-90)Page 327.4
l Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 5b5)(Includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 OTHER PURCHASED POWER
2 American Electric Power OS WSPP NA NA NA
3 American Electric Power SF WSPP NA NA NA
4 AlbedaPowerPool SF -NA NA NA
5 Amoco Energy Trading Corporation SF WSPP NA NA NA
6 Anaheim City of OS WSPP NA NA NA
7 Anaheim City of SF WSPP NA NA NA
8 Aquilla Power Corp SF WSPP NA NA NA
9 Aquilla Power Corp OS WSPP NA NA NA
10 Arizona Electric Power Coop,Inc.SF WSPP NA NA NA
11 Arizona Electric Power Coop,Inc OS WSPP NA NA NA
12 Arizona Public Service Co.OS WSPP NA NA NA
13 Arizona Public Service SF WSPP NA NA NA
14 Avista Corp.WWP Div OS WSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.5
Name of Respondent This Re ort Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU (CHASED POWER(Account 555)(Õontinued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriatedesignationforthecontract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demandduringthehour(60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (I).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlementamountforthenetreceiptofenergy.If more energy was delivered than received,enter a negative amount.If the settlement amount (I)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
I POWER EXCHANGES I COST/SETTLElv ENT OF POWERMegaWttHolire
I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(l)(m)
1
5C 4,00C 4,000 2
1,297,267 85,197,02E 85,197,026 3
6,076 472,192 472,193 4
10,80C 537,00C 537,000 5
17C 2,60C 2,600 6
173,814 9,471,39E -1,086,927 8,384,472 7
5,50C 390,30C 390.300 8
1,022,422 63,855,552 63,855,552 9
-1,500 -1,500 10
-50C -10,95C -10,950 11
855 25,31C 25,310 12
297,784 15,600 21,509,13E 21,524,736 13
13,44E 495,912 495,913 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,816
FERC FORM NO.1 (ED.12-90)Page 327.5
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De Tiand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Avista Corp.WWP Div SF WSPP NA NA NA
2 Avista Energy,Inc OS WSPP NA NA NA
3 Avista Energy,Inc SF WSPP NA NA NA
4 Cities of Azusa,Banning &Colton SF WSPP NA NA NA
5 Basin Electric Power Cooperative SF WSPP NA NA NA
6 Benton County PUD SF WSPP NA NA NA
7 Bonneville Fuels Management Corp SF -NA NA NA
8 Bonneville Power Administration OS WSPP NA NA NA
9 Bonneville Power Administration SF WSPP NA NA NA
10 BP Energy Company SF WSPP NA NA NA
11 Burbank City Of SF WSPP NA NA NA
12 California Dept of Water Resources OS WSPP NA NA NA
13 California Dept of Water Resources SF WSPP NA NA NA
14 California ISO SF -NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.6
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
PU (ÖHASED POWËR(Account 555)(Continued)(including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriate
designation for the contract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,as
identified in column (b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enter
the monthly average billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the
average monthly coincident peak (CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly
NCP demand is the maximum metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand
during the hour (60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)
must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (I).Report in column (m)
the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (l)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by the
agreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COST/SETTLElvENT OF POWERMagaWattHours I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
965,397 83,381,64E 21,485 83,403,130 1
2,462 41,73E 41,739 2
1,401,901 57,634,02E -57,634,029 3
28,49C 1,474,27C 1,474,270 4
182,784 8,983,20C 91,974 9,075,174 5
5,952 1,019,00E 1,019,008 6
12,03E 236,547 236,547 7
13,491 388,621 388,621 8
551,25C 20,000 38,569,341 38,589,341 9
89,60C 6,783,30C 6,783,300 10
29C 47,60C 47,600 11
40C 34,40C 34,400 12
6,68E 421,872 421,872 13
7,241 3,064,24E 3,064,248 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,81E
FERC FORM NO.1 (ED.12-90)Page 327.6
'Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual DeTiand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 California Power Exchange OS -NA NA NA
2 California Power Exchange SF -NA NA NA
3 Candela Energy Corporation OS -NA NA NA
4 Candela Energy Corporation SF -NA NA NA
5 Cargill-Alliant,LLC SF WSPP NA NA NA
6 Cargill-Alliant.LLC OS WSPP NA NA NA
7 Chelan CO PUD SF WSPP NA NA NA
8 Chelan Co PUD OS WSPP NA NA NA
9 Citizens Power Sales SF WSPP NA NA NA
10 Coastal Merchant Energy SF WSPP NA NA NA
11 Colorado River Commission of Nevada OS -NA NA NA
12 Colorado River Commission of Nevada SF -NA NA NA
13 Colorado Springs Utilities OS WSPP NA NA NA
14 Colorado Springs Utilities SF WSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.7
Name of Respondent This Report is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU (CHASED ÞOWER(Account 555)(Óontinued)(including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriatedesignationforthecontract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly
NCP demand is the maximum metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand
during the hour (60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)
must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (l).Explain in a footnote all components of the amount shown in column (I).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (I)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COST/SETTLEMENT OF POWERM09WattHolir I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement (S)(g)(h)(i)(j)(k)(1)(m)
53E 14,412 14,413 1
693,166 99,072,58E 99,072,588 2
10C 23,30C 23,300 3
26,876 4,151,052 4,151,052 4
2,581 404,97E 404,978 5
158,32E 13,107,581 13,107,581 6
-186 -2,07E -2,078 7
32,50C 3,386,80C 3,386,800 8
372,15C 11,894,445 -3,300 11,891,145 9
1,20C 300,00C 300,000 10
3C 1,141 1,141 11
1,427 93,522 93,523 12
27,242 3,058,667 3,058,667 13
1,976 242,155 242,155 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,81E
FERC FORM NO.1 (ED.12-90)Page 327.7
l Name of Respondent This Re ort Is:Date of Report Year of Report I
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 City of Colton SF WSPP NA NA NA
2 Con Agra Energy Services Inc.SF WSPP NA NA NA
3 Constellation Power Source SF WSPP NA NA NA
4 Coral Power,LLC OS WSPP NA NA NA
5 Coral Power,LLC SF WSPP NA NA NA
6 Cowlitz Co,PUD SF -NA NA NA
7 Deseret Generation &Transmission SF WSPP NA NA NA
8 Duke Energy Trading and Marketing OS WSPP NA NA NA
9 Duke Energy Trading and Marketing SF WSPP NA NA NA
10 Dynergy Power Marketing SF WSPP NA NA NA
11 Edision Mission Marketing &Trading SF WSPP NA NA NA
12 EIPaso Electric Company SF WSPP NA NA NA
13 ElPaso Merchant Energy L.P.SF WSPP NA NA NA
14 Energy Authority,The OS WSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.8
Name of Respondent This Report Is:Date of Report Year of Report(1)QX An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU (CHA POWER(Account 555)(Continued)ncludmg power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriate
designation for the contract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enter
the monthly average billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the
average monthly coincident peak (CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand
during the hour (60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)
must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (l).Report in column (m)
the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (I)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by the
agreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
I POWER EXCHANGES COST/SETTLEIVENT OF POWERMP0aWattHolire I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
1,65E 89,58E 89,586 1
6,40C 224,90C 224,900 2
798,235 55,605,815 55,605,815 3
92 35,80C 35,800 4
64,392 8,343,190 8,343,190 5
32C 16,00C 16,000 6
110,65C 3,190,581 3,190,581 7
6C 3,30C 3,300 8
924,844 55,259,43E 55,259,438 9
533,004 42,459,157 42,459,157 10
416,25C 41,153,575 41,153,575 11
50,00C 1,492,50C 1,492,500 12
768,776 41,600 65,927,89C 65,969,490 13
2,715 114,105 114,105 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,81E
FERC FORM NO.1 (ED.12-90)Page 327.8
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average Average
No.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Energy Authority,The SF WSPP NA NA NA
2 Energy Services,Inc IF -NA NA NA
3 EngageEnergyUS SF \NSPP NA NA NA
4 Enron Power Marketing,Inc.OS WSPP NA NA NA
5 Enron Power Marketing,Inc.SF WSPP NA NA NA
6 Eugene Water &Electrical Board SF WSPP NA NA NA
7 Eugene Water &Electrical Board OS WSPP NA NA NA
8 Astaris Idaho,LLC SF -NA NA NA
9 Franklin County PUD SF WSPP NA NA NA
10 Glendale,City of SF WSPP NA NA NA
11 Grant County PUD OS WSPP NA NA NA
12 Grant County PUD SF WSPP NA NA NA
13 Gray's Harbor PUD SF WSPP NA NA NA
14 Illinova Energy Partners SF WSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.9
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU 40HASED PO\M-R(Account 555)(Continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriate
designation for the contract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demandduringthehour(60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (l).Explain in a footnote all components of the amount shown in column (I).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (l)
include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by the
agreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
I POWER EXCHANGES 'COST/SETTLEIVENT OF POWERMR0aWattHolirs!
,l.ine
Purchased MegaWatt Hours |MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
1,05C 101,25C 101,250 1
878,40C 13,231,837 13,231,837 2
39,00C 1,711,874 1,711,874 3
2,551 76,152 76,153 4
4,028,882 59,800 300,547,711 300,607,511 5
6C 1,44C 1,440 6
44,35E 3,340,941 3,340,941 7
17,39C 1,731,642 1,731,643 8
1,08C 163,48E 163,488 9
3,79E 1,119,50C 1,119,500 10
1,01C 365,48C 365,480 11
187,134 9,820,352 9,820,352 12
64,69E 1,529,285 1,529,285 13
15,332 351,592 351,593 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,81E
FERC FORM NO.1 (ED.12-90)Page 327.9
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Koch Energy Trading SF WSPP NA NA NA
2 Los Angeles Water &Power Department OS WSPP NA NA NA
3 Los Angeles Water and Power Dept SF WSPP NA NA NA
4 McMinnville City of SF WSPP NA NA NA
5 Merchant Energy Group of the Americas SF WSPP NA NA NA
6 Merrill Lynch Capital Services,Inc SF WSPP NA NA NA
7 MidAmerican Energy Corp OS WSPP NA NA NA
8 MidAmerican Energy Corp SF WSPP NA NA NA
9 MIECO,Inc SF WSPP NA NA NA
10 Montana Power Company SF WSPP NA NA NA
11 Morgan Stanley Capital Group SF WSPP NA NA NA
12 Municipal Energy Agency of Nebraska OS WSPP NA NA NA
13 Municipal Energy Agency of Nebraska SF WSPP NA NA NA
14 NevadaPowerCompany OS \NSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.10
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,000
PU (CHA D PO\ÁlER(Account 555)(Continued)luding power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriate
designation for the contract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demandduringthehour(60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (l).Explain in a footnote all components of the amount shown in column (1).Report in column (m)
the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (1)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by the
agreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
|POWER EXCHANGES COST/SETTLElvENT OF POWERMegaWattHolirs I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
81,20C 4,779,76C 4,779.760 1
126 50,00C 50,000 2
60,932 1,040,074 1,430,560 2,470,634 3
4,697 391,711 391,711 4
22,40C 655,60C 655,600 5
96,426 11,719,80C 11,719,800 6
25,305 821,975 821,975 7
19,72C 477,865 477,865 8
168,775 7,106,04C 7,106,040 9
43,802 6,142,742 6,142,742 10
143,80C 7,762,30C 7,762,300 11
79,69C 11,635,45E 11,635,459 12
6,93C 572,635 572,635 13
5C 1,10C 1,100 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,816
FERC FORM NO.1 (ED.12-90)Page 327.10
Name of Respondent This Report Is:Date of Report Year of Report(1)DX An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 565)(including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De Tiand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Deman<Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 NevadaPowerCompany SF WSPP NA NA NA
2 Northern California Power Agency OS WSPP NA NA NA
3 Northern California Power Agency SF WSPP NA NA NA
4 OGE Energy Resources OS WSPP NA NA NA
5 Omaha Public Power District OS WSPP NA NA NA
6 Omaha Public Power District SF WSPP NA NA NA
7 Pacific Northwest Generating Co-op SF WSPP NA NA NA
8 Pacificorp Power Marketing OS WSPP NA NA NA
9 Pacificorp Power Marketing SF WSPP NA NA NA
10 PacifiCorp Wholesale OS WSPP NA NA NA
11 PacifiCorp Wholesale OS WSPP NA NA NA
12 PacifiCorp Wholesale SF WSPP NA NA NA
13 PacifiCorp Wholesale SF WSPP NA NA NA
14 Pasadena City of SF WSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.11
Name of Respondent This Report Is:Date of Report Year of Report(1)OX An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU RCHA POWER(Account 555)(Continued)uding power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriatedesignationforthecontract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demandduringthehour(60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthoursofpowerexchangesreceivedanddelivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (1).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlementamountforthenetreceiptofenergy.If more energy was delivered than received,enter a negative amount.If the settlement amount (I)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES I COST/SETTLEMENT OF POWERMegaWattHours I.ine
Purchased MegaWatt Hours i MegaWatt Hours Demand Charges Energy Charges 'Other Charges i Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
193,517 10,294,314 10,294,314 1
64 5,44C 5,440 2
3,17E 412,85E 412,856 3
571 14,38E 14,386 4
6,29C 162,14C 162,140 5
16,465 516,262 516,263 6
3,40C 55,25C 55,250 7
2,95C 815,12C 815,120 8
212,32C 7,409,42C 7,409,420 9
15C 3,30C 3,300 10
6,182 162,725 162,725 11
-4E -1,42E -1,426 12
565,072 52,782,197 52,782,197 13
96C 16,44C 16,440 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,816
FERC FORM NO.1 (ED.12-90)Page 327.11
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(including power exchanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
Classifi-Schedule or Monthly Billing Average |Average
No.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demanti Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 PECO Energy SF WSPP NA NA NA
2 PECOEnergy OS \NSPP NA NA NA
3 PG&E Energy Trading SF WSPP NA NA NA
4 Pinnacle West Capital Corp SF WSPP NA NA NA
5 Plains Electric Generation &Transmsn OS WSPP NA NA NA
6 Plains Electric Generation &Transmsn SF WSPP NA NA NA
7 Platte River Power Authority OS WSPP NA NA NA
8 Platte River Power Authority SF WSPP NA NA NA
9 Portland General Electric OS WSPP NA NA NA
10 Portland General Electric SF WSPP NA NA NA
11 Power Company of America SF WSPP NA NA NA
12 Powerex Corp OS WSPP NA NA NA
13 Powerex Corp SF WSPP NA NA NA
14 PP&L Montana,LLC.OS WSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.12
l Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU RCHA$Eb ÞQWER(Account 555)(continued)(Including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriatedesignationforthecontract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demandduringthehour(60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthoursofpowerexchangesreceivedanddelivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (l).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlementamountforthenetreceiptofenergy.If more energy was delivered than received,enter a negative amount.If the settlement amount (1)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
'POWER EXCHANGES COST/SETTLElvENT OF POWERDaWattHolirs Line
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(l)(m)
40C 60,80C 60,800 1
21,975 1,346,65C 1,346,650 2
745,00C 55,411,884 55,411,884 3
148,117 11,867,882 11,867,883 4
5,50C 148,04C 148,040 5
9,415 187,015 187,015 6
34,796 2,213,494 2,213,494 7
28E 10,06A 10,064 8
485 32,724 32,724 9
705,73C 39,442,98E 39,442,988 10
-362,500 -362,500 11
11,221 406,94C 406,940 12
314,88E 36,789,556 36,789,558 13
16,16E 626,73C 626,730 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,816
FERC FORM NO.1 (ED.12-90)Page 327.12
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 565)(Including power exchanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e,g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term senrice from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 PP&L Montana,LLC.SF WSPP NA NA NA
2 Public Service of Colorado OS WSPP NA NA NA
3 Public Service of Colorado SF WSPP NA NA NA
4 Public Service of New Mexico OS WSPP NA NA NA
5 Public Service of New Mexico OS WSPP NA NA NA
6 Public Service of New Mexico SF WSPP NA NA NA
7 Puget Sound Energy SF WSPP NA NA NA
8 Puget Sound Energy OS WSPP NA NA NA
9 Redding City of SF WSPP NA NA NA
10 Reliant Energy Services SF WSPP NA NA NA
11 City of Richland SF WSPP NA NA NA
12 City of Riverside SF WSPP NA NA NA
13 Rocky Mountain Generation Company OS WSPP NA NA NA
14 Rocky Mountain Generation Company SF WSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.13
Name of Respondent This Report Is.Date of Report Year of Report(1)QX An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ÞU RÖHAS ÖWEA(Account 555)(Öontinued)(I mg power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriate
designation for the contract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,as
identified in column (b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enter
the monthly average billing demand in column (d),the average monthly non-coincident peak (NCP)demand in column (e),and the
average monthly coincident peak (CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).Monthly
NCP demand is the maximum metered hourly (60-minute integration)demand in a month.Monthly CP demand is the metered demand
during the hour (60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)
must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,including
out-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (I).Report in column (m)
the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (l)
include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by the
agreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
I POWER EXCHANGES I COST/SETTLEMENT OF POWER IMP0aWattHnilr I ine
Purchased MegaWatt Hours i MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(I)(m)
302,622 33,488,62E 33,488,628 1
18,157 1,591,33E 1,591,339 2
270,982 18,228,80E 18,228,806 3
-175 -4,572 -4,573 4
30,343 938,336 938,335 5
331,376 21,638,624 21,638,624 6
8,502 471,697 471,697 7
481,18E 30,421,987 30,421,987 8
1,57E 88,45€88,456 9
183,706 13,869,824 13,869,824 10
5,744 486,672 486,672 11
76,836 5,686,552 5,686,552 12
145,236 10,308,632 10,308,632 13
138,782 9,317,117 9,317,117 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,81€
FERC FORM NO.1 (ED.12-90)Page 327.13
'Name of Respondent This Re ort is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(Includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-definedcategories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demand Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Sacramento Municipal Utility Dist SF WSPP NA NA NA
2 Salt River Project OS WSPP NA NA NA
3 Salt River Project SF WSPP NA NA NA
4 San Diego Gas &Electric OS WSPP NA NA NA
5 San Diego Gas &Electric SF WSPP NA NA NA
6 City of Seattle OS WSPP NA NA NA
7 City of Seattle SF WSPP NA NA NA
8 Sempra Energy Trading Corp OS WSPP NA NA NA
9 Sempra Energy Trading Corp SF WSPP NA NA NA
10 Sierra Pacific OS WSPP NA NA NA
11 Sierra Pacific SF WSPP NA NA NA
12 Silicone Valley Power SF WSPP NA NA NA
13 Simplot Fertilizer Company SF -NA NA NA
14 Snohomish County PUD OS WSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.14
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU RCHA PÖWER(Account 555)(Continued)ncluding power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriatedesignationforthecontract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demandduringthehour(60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthoursofpowerexchangesreceivedanddelivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (l).Explain in a footnote all components of the amount shown in column (I).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlementamountforthenetreceiptofenergy.If more energy was delivered than received,enter a negative amount.If the settlement amount (I)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COST/SETTLElv ENT OF POWERWlegaWattHolirs
I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+1)No.Received i Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(1)(m)
3,341 181,204 181.204 1
11,411 684,694 684,694 2
289,16E 20,270,181 20,270,181 3
24 48C 480 4
4,341 182,65E 182,658 5
6,931 212,14E 212,149 6
241,172 16,417,541 16,417,541 7
5C 1,00C 1,000 8
395,844 30,905,97C 30,905,970 9
2,11E 71,29C 71,290 10
554,083 43,396,282 43,396,282 11
179,60C 13,630,292 13,630,292 12
2,772 749,885 749,885 13
9,452 362,79E 362,799 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,81E
FERC FORM NO.1 (ED.12-90)Page 327.14
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(Includmg power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-definedcategories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Deman<Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Snohomish County PUD SF WSPP NA NA NA
2 Southern Company Energy Marketing SF WSPP NA NA NA
3 Statoil Energy Inc.SF WSPP NA NA NA
4 Tacoma Power OS WSPP NA NA NA
5 Tacoma Power SF WSPP NA NA NA
6 Tenaska Power Services OS WSPP NA NA NA
7 Tenaska Power Services SF WSPP NA NA NA
8 Tillamook Peoples Utility District SF -NA NA NA
9 Tractebel Energy Marketing SF WSPP NA NA NA
10 Trans Alta Energy Marketing OS WSPP NA NA NA
11 Trans Alta Energy Marketing SF WSPP NA NA NA
12 Trans Canada Power SF WSPP NA NA NA
13 Tri-State Generation &Transmission OS WSPP NA NA NA
14 Tri-State Generation &Transmission SF WSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.15
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ÞU RCHA POWËR(Account 555)(Continued)udmg power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriate
designation for the contract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demandduringthehour(60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (1).Explain in a footnote all components of the amount shown in column (I).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (I)
include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES COST/SETTLElv ENT OF POWER I
.IMeg=W tt Houre
,I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges |Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
40,502 4,887,41E 4,887,418 1
107,20E 25,920 6,881,06E 6,906,989 2
61,60C 2,476,32C 2,476,320 3
4,681 157,952 157,952 4
21,29E 2,656,56E 2,656,566 5
322 17,934 17,934 6
112 6,16C 6,160 7
325 56,36C 56,360 8
248,00C 13,614,940 13,614,940 9
2,392 368,255 368,255 10
211,634 19,945,62E 19,945,628 11
12,682 1,955,625 1,955,625 12
18,872 1,351,93C 1,351,930 13
97,91C 3,589,58C 3,589,580 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,816
FERC FORM NO.1 (ED.12-90)Page 327.15
Name of Respondent This Report Is:Date of Report Year of Report
(1)QX An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
.Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Tucson Electric Power OS WSPP NA NA NA
2 Tucson Electric Power SF WSPP NA NA NA
3 Tucson Electric Power SF WSPP NA NA NA
4 Turlock Irrigation District SF WSPP NA NA NA
5 Utah Associated Mun Power System OS WSPP NA NA NA
6 Utah Associated Mun Power System OS WSPP NA NA NA
7 Utah Associated Mun Power System SF WSPP NA NA NA
8 Utah Associated Mun Power System SF WSPP NA NA NA
9 Utah Municipal Power Agency OS -NA NA NA
10 Utah Municipal Power Agency SF -NA NA NA
11 UtiliCorp United OS WSPP NA NA NA
12 UtiliCorp United SF WSPP NA NA NA
13 Vanalco,Inc SF -NA NA NA
14 Western Area Power Administration SF WSPP NA NA NA
Total
FERC FORM NO.1 (ED.12-90)Page 326.16
Name of Respondent This Report is:Date of Report Year of Report(1)QX An Original (Mo,Da,Yr)2 00idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,O
ÞU RCHA POWl-R(Account 555)(Continued)ncluding power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriate
designation for the contract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demandduringthehour(60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthoursofpowerexchangesreceivedanddelivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (l).Explain in a footnote all components of the amount shown in column (1).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlementamountforthenetreceiptofenergy.If more energy was delivered than received,enter a negative amount.If the settlement amount (I)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must bereportedasPurchasesonPage401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
I POWER EXCHANGES I COST/SETTLEMENT OF POWERMegaWattHolirs|,I I ine
Purch d MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.ase Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
50,57E 3,196,05E 3,196,058 1
15C 2,85C 2,850 2
83,322 6,183,60C 6,183,600 3
15,18E 952,23E 952,239 4
12C 1,532 1,532 5
59,342 2,484,865 2,484,865 6
-935 3,39C 3,390 7
336,235 14,390,10E 14,390,109 8
41,542 2,577,562 2,577,563 9
21,71E 1,764,027 1,764,027 10
71,18C 4,231,941 4,231,941 11
1,987 64,862 64,863 12
40,154 5,001,99E 5,001,998 13
4E 1,286 1,286 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,81E
FERC FORM NO.1 (ED.12-90)Page 327.16
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,000
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
IU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Western Area Power Administration OS WSPP NA NA NA
2 Western Area Power Administration SF WSPP NA NA NA
3 Western Resources,Inc OS WSPP NA NA NA
4 Western Resources,Inc SF WSPP NA NA NA
5 Williams Energy Marketing &Trading OS WSPP NA NA NA
6 Williams Energy Marketing &Trading SF WSPP NA NA NA
7 less non-operating purchases
8 less bad debt write-off
9
10 Power Exchanges
11 Anaheim City of EX WSPP
12 Bonneville Power Administration EX 22
13 Douglas County P.U.D.EX T1R2
14 City of Seattle EX 71
Total
FERC FORM NO.1 (ED.12-90)Page 326.17
Name of Respondent This Report is:Date of Report Year of Report(1)DXAn Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PIJ RCHA D POWER(Account 555)(Continued)ncluding power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriate
designation for the contract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,as
identified in column (b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand
during the hour (60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)
must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,including
out-of-period adjustments,in column (l).Explain in a footnote all components of the amount shown in column (1).Report in column (m)the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (l)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES I COST/SETTLEMENT OF POWERMegaWattHours I ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges i Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)
(g)(h)(i)(j)(k)(1)(m)
275,922 22,079,62C 22,079,620 1
139,822 8,469,97E 8,469,978 2
5,12E 217,772 217,772 3
705 31,725 31,725 4
15C 1,75C 1,750 5
885,09E 49,680 55,050,927 55,100,607 6
-23,266,112 -1,516,252,684 -1,516,252,684 7
38,81C 38,810 8
9
10
429,292 358,388 11
527,046 486,396 12
350 300 13
126,121 125,850 14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,816
FERC FORM NO.1 (ED.12-90)Page 327.17
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PURCHASED POWER (Account 555)(Including power excnanges)
1.Report all power purchases made during the year.Also report exchanges of electricity (i.e.,transactions involving a balancing of
debits and credits for energy,capacity,etc.)and any settlements for imbalanced exchanges.
2.Enter the name of the seller or other party in an exchange transaction in column (a).Do not abbreviate or truncate the name or use
acronyms.Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
3.In column (b),enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:
RQ -for requirements service.Requirements service is service which the supplier plans to provide on an ongoing basis (i.e.,the
supplier includes projects load for this service in its system resource planning).In addition,the reliability of requirement service must
be the same as,or second only to,the supplier's service to its own ultimate consumers.
LF -for long-term firm service."Long-term"means five years or longer and "firm"means that service cannot be interrupted for
economic reasons and is intended to remain reliable even under adverse conditions (e.g.,the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of LF service).This category should not be used for long-term firm service firm service
which meets the definition of RQ service.For all transaction identified as LF,provide in a footnote the termination date of the contract
defined as the earliest date that either buyer or seller can unilaterally get out of the contract.
IF -for intermediate-term firm service.The same as LF service expect that "intermediate-term"means longer than one year but less
than five years.
SF -for short-term service.Use this category for all firm services,where the duration of each period of commitment for service is one
year or less.
LU -for long-term service from a designated generating unit."Long-term"means five years or longer.The availability and reliability of
service,aside from transmission constraints,must match the availability and reliability of the designated unit.
lU -for intermediate-term service from a designated generating unit.The same as LU service expect that "intermediate-term"means
longer than one year but less than five years.
EX -For exchanges of electricity.Use this category for transactions involving a balancing of debits and credits for energy,capacity,
etc.and any settlements for imbalanced exchanges.
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as all
non-firm service regardless of the Length of the contract and service from designated units of Less than one year.Describe the nature
of the service in a footnote for each adjustment.
Line Name of Company or Public Authority Statistical FERC Rate Average Actual De nand (MW)
Classifi-Schedule or Monthly Billing Average AverageNo.(Footnote Affiliations)cation Tariff Number Demand (MW)Monthly NCP Demant Monthly CP Demand
(a)(b)(c)(d)(e)(f)
1 Montana Power Company EX 70
2 Bonneville Power Administration EX WSPP
3 PacifiCorp Wholesale EX WSPP
4 City of Seattle EX WSPP
5 Arizona Public Service EX WSPP
6 Montana Power Company EX WSPP
7 Portland General Electric EX WSPP
8 Puget Sound Energy EX WSPP
9 Sierra Pacific Power EX WSPP
10 Snohomish County PUD EX WSPP
11 Avista Corp -WWP Div EX WSPP
12 Less Non-Op transactions
13 Acct valuation City of Seattle exc
14 Acct valuation Montana Power exc
Total
FERC FORM NO.1 (ED.12-90)Page 326.18
Name of Respondent This Report is:Date of Report Year of Report(1)DX An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PU RCHAŠEDPOWʾ(Account 555)(Ôontinued)(including power exchanges)
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reporting
years.Provide an explanation in a footnote for each adjustment.
4.In column (c),identify the FERC Rate Schedule Number or Tariff,or,for non-FERC jurisdictional sellers,include an appropriatedesignationforthecontract.On separate lines,list all FERC rate schedules,tariffs or contract designations under which service,asidentifiedincolumn(b),is provided.
5.For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer)basis,enterthemonthlyaveragebillingdemandincolumn(d),the average monthly non-coincident peak (NCP)demand in column (e),and theaveragemonthlycoincidentpeak(CP)demand in column (f).For all other types of service,enter NA in columns (d),(e)and (f).MonthlyNCPdemandisthemaximummeteredhourly(60-minute integration)demand in a month.Monthly CP demand is the metered demand
during the hour (60-minute integration)in which the supplier's system reaches its monthly peak.Demand reported in columns (e)and (f)
must be in megawatts.Footnote any demand not stated on a megawatt basis and explain.
6.Report in column (g)the megawatthours shown on bills rendered to the respondent.Report in columns (h)and (i)the megawatthours
of power exchanges received and delivered,used as the basis for settlement.Do not report net exchange.
7.Report demand charges in column (j),energy charges in column (k),and the total of any other types of charges,includingout-of-period adjustments,in column (I).Explain in a footnote all components of the amount shown in column (I).Report in column (m)
the total charge shown on bills received as settlement by the respondent.For power exchanges,report in column (m)the settlement
amount for the net receipt of energy.If more energy was delivered than received,enter a negative amount.If the settlement amount (1)include credits or charges other than incremental generation expenses,or (2)excludes certain credits or charges covered by theagreement,provide an explanatory footnote.
8.The data in column (g)through (m)must be totalled on the last line of the schedule.The total amount in column (g)must be
reported as Purchases on Page 401,line 10.The total amount in column (h)must be reported as Exchange Received on Page 401,
line 12.The total amount in column (i)must be reported as Exchange Delivered on Page 401,line 13.
9.Footnote entries as required and provide explanations following all required data.
POWER EXCHANGES I COST/SETTLEMENT OF POWERMegaWattHnnroI i ine
Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l)No.Received Delivered ($)($)($)of Settlement ($)(g)(h)(i)(j)(k)(I)(m)
118,800 108,000 1
68,239 17,541 2
129,322 258,334 3
3,422 4
2,508 5
11,098 6
178 7
10,886 8
18,181 9
1,676 10
9,777 11
-429,292 -358,388 12
13
14
4,299,948 975,808 1,048,217 3,027,724 395,065,300 89,792 398,182,816
FERC FORM NO.1 (ED.12-90)Page 327.18
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTE DATA
Schedule Page:326 Line No.:4 Column:a
The Tamarack Energy Partnership demand readings are taken from an electronic demand
recorder provided
by Idaho Power,the actual demand is not used in determining the cost of energy.
Schedule Page:326.1 Line No.:2 Column:b
non-firm purchases.
Schedule Page:326.1 Line No.:8 Column:b
non-firm purchases.
Schedule Page:326.3 Line No.:9 Column:b
non-firm purchases
Schedule Page:326.4 Line No.:11 Column:b
non-firm purchases.
Schedule Page:326.4 Line No.:12 Column:a
Energy differences between scheduled and actual receipts from small power producers.
Schedule Page:326.5 Line No.:2 Column:b
non-firm purchases.
Schedule Page:326.5 Line No.:6 Column:b
non-firm purchases.
Schedule Page:326.5 Line No.:7 Column:I
Liquidated Damages
Schedule Page:326.5 Line No.:9 Column:b
Non-Firm purchases
Schedule Page:326.5 Line No.:10 Column:I
1998 corrections
Schedule Page:326.5 Line No.:11 Column:b
non-firm purchases
Schedule Page:326.5 Line No.:12 Column:b
non-firm purchases
Schedule Page:326.5 Line No.:14 Column:b
Non-firm purchases
Schedule Page:326.6 Line No.:1 Column:I
Liquidated Damages
Schedule Page:326.6 Line No.:2 Column:b
Non-firm purchases
Schedule Page:326.6 Line No.:5 Column:I
Liquidated Damages
Schedule Page:326.6 Line No.:8 Column:b
non-firm purchases
Schedule Page:326.6 Line No.:12 Column:b
non-firm purchases.
Schedule Page:326.7 Line No.:1 Column:b
non-firm purchases
Schedule Page:326.7 Line No.:3 Column:b
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Report is:Date of Report Year of Report(1)X_An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTE DATA
non-firm purchases
Schedule Page:326.7 Line No.:6 Column:b
non-firm purchases
Schedule Page:326.7 Line No.:8 Column:b
non-firm purchases
Schedule Page:326.7 Line No.:9 Column:ILiquidatedDamages
Schedule Page:326.7 Line No.:11 Column:b
non-firm purchases.
Schedule Page:326.7 Line No.:13 Column:b
non-firm purchases.
Schedule Page:326.8 Line No.:4 Column:b
non-firm purchases.
Schedule Page:326.8 Line No.:8 Column:b
non-firm purchases.
Schedule Page:326.8 Line No.:14 Column:b
non-firm purchases.
Schedule Page:326.9 Line No.:4 Column:b
non-firm purchases.
Schedule Page:326.9 Line No.:7 Column:b
non-firm purchases.
Schedule Page:326.9 Line No.:11 Column:b
non-firm purchases.
Schedule Page:326.10 Line No.:2 Column:b
non-f irm purchases .
Schedule Page:326.10 Line No.:3 Column:I
Turbine expenses
Schedule Page:326.10 Line No.:7 Column:b
non-firm purchases.
Schedule Page:326.10 Line No.:12 Column:b
non-firm purchases.
Schedule Page:326.11 Line No.:2 Column:b
non-firm purchases.
Schedule Page:326.11 Line No.:4 Column:b
non-firm purchases.
Schedule Page:326.11 Line No.:5 Column:b
non-firm purchases.
Schedule Page:326.11 Line No.:8 Column:b
non-firm purchases.
Schedule Page:326.11 Line No.:10 Column:b
non-firm purchases.
Schedule Page:326.11 Line No.:11 Column:b
non-firm purchases.
Schedule Page:326.12 Line No.:2 Column:b
non-firm purchases.
Schedule Page:326.12 Line No.:5 Column:b
non-firm purchases.
FERC FORM NO.1 (ED.12-87)Page450.1
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTE DATA
Schedule Page:326.12 Line No.:7 Column:b
non-firm purchases.
Schedule Page:326.12 Line No.:9 Column:b
non-firm sales.
Schedule Page:326.12 Line No.:11 Column:I
Liquidated damages
Schedule Page:326.12 Line No.:12 Column:b
non-firm purchases.
Schedule Page:326.12 Line No.:14 Column:b
non-firm purchases.
Schedule Page:326.13 Line No.:2 Column:b
non-firm purchases.
Schedule Page:326.13 Line No.:4 Column:b
non-firm purchases.
Schedule Page:326.13 Line No.:5 Column:b
non-firm purchases.
Schedule Page:326.13 Line No.:8 Column:b
non-firm purchases.
Schedule Page:326.13 Line No.:13 Column:b
non-firms purchases.
Schedule Page:326.14 Line No.:2 Column:b
non-firm purchases.
Schedule Page:326.14 Line No.:4 Column:b
non-firm purchases.
Schedule Page:326.14 Line No.:6 Column:b
non-firm purchases.
Schedule Page:326.14 Line No.:8 Column:b
non-firm purchases.
Schedule Page:326.14 Line No.:10 Column:b
non-firm purchases.
Schedule Page:326.14 Line No.:14 Column:b
non-firm purchases.
Schedule Page:326.15 Line No.:4 Column:b
non-firms purchases.
Schedule Page:326.15 Line No.:6 Column:b
non-firm purchases.
Schedule Page:326.15 Line No.:10 Column:b
non-firm purchases.
Schedule Page:326.15 Line No.:13 Column:b
non-firm purchases.
Schedule Page:326.16 Line No.:1 Column:b
non-firm purchases.
Schedule Page:326.16 Line No.:5 Column:b
non-firm purchases.
Schedule Page:326.16 Line No.:6 Column:b
non-firm purchases.
Schedule Page:326.16 Line No.:9 Column:b
FERC FORM NO.1 (ED.12-87)Page450.2
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTE DATA
non-firm purchases.
Schedule Page:326.16 Line No.:11 Column:b
non-firm purchases.
Schedule Page:326.17 Line No.:1 Column:b
non-firm purchases.
Schedule Page:326.17 Line No.:3 Column:b
non-firm purchases.
Schedule Page:326.17 Line No.:5 Column:b
non-firm purchases.
Schedule Page:326.17 Line No.:7 Column:a
transactions identified as non-operating and properly accounted for in account 421.Schedule Page:326.18 Line No.:2 Column:b
lines 2 thru 11 are scheduled losses not removed with loss transactions.Schedule Page:326.18 Line No.:12 Column:a
transactions identified as non-operating and properly accounted for in account 421.
FERC FORM NO.1 (ED.12-87)Page 450.3
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
|RANSMISSION OF ELEC l RICI \Y EOR OTHERS (Account 456)(Including transactions referred to as 'wheeling')
1.Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,municipalities,other public
authorities,qualifying facilities,non-traditional utility suppliers and ultimate customers.
|2.Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a),(b)and (c).
3.Report in column (a)the company or public authority that paid for the transmission service.Report in column (b)the company or
public authority that the energy was received from and in column (c)the company or public authority that the energy was delivered to.
Provide the full name of each company or public authority.Do not abbreviate or truncate name or use acronyms.Explain in a footnote
any ownership interest in or affiliation the respondent has with the entities listed in columns (a),(b)or (c)
4.In column(d)enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
LF -for Long-term firm transmission service."Long-term"means one year or longer and "firm"means that service cannot be interrupted
for economic reasons and is intended to remain reliable even under adverse conditions.For all transactions identified as LF,provide in
a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the
contract.
SF -for short-term firm transmission service.Use this category for all firm services,where the duration of each period of commitment
for service is less than one year.
Line Payment By Energy Received From Energy Delivered To Statistical
No (Company of Public Authority)(Company of Public Authority)(Company of Public Authority)Classifi-
(Footnote Affiliation)(Footnote Affiliation)(Footnote Affiliation)cation
(a)(b)(c)(d)
1 Bonneville Power Administration Bonneville Power Administration Oregon Trails Electric Co-op LF
2 """"""Bonneville Power Administration LF
3 """"""Vigilante LF
4 Milner irrigation District Bureau of Reclamation Milner Irrigation LF
5 Arizona Public Service Arizona Public Service Bonneville Power Administation LF
6 Arizona Public Service Arizona Public Service Bonneville Power Administration OS
7 Aquilla Power Corporation Aquilla Power Corporation Bonneville Power Administration OS
8 Transalta Energy Transalta Energy Pacificorp -East OS
9 Montana Power Company Montana Power Company PacifiCorp -East OS
10 BC Hydro (Powerx)BC Hydro (Powerx)Sierra Pacific Power Company OS
11 PacifCorp PacifiCorp -Wyoming PacifiCorp -East LF
12 "PacifiCorp -East PacifiCorp -West LF
13 "PacifiCorp -West PacifiCorp -East LF
14 "PacifiCorp PacifiCorp OS
15 Southern Energy Marketing Southern Energy Marketing PacifiCorp -East SF
16 """Southern Energy Marketing PacifiCorp -West OS
17 Puget Sound Power &Light Puget Sound Power &Light Bonneville Power Administration OS
TOTAL
FERC FORM NO.1 (ED.12-90)Page 328
Name of Respondent This Report Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000ldahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
|RANSMISSIOrd OF ELECINICI lY FOR Ul HERS (Account 456)(Continued)(including transactions reffered to as 'wheeling')
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as allnonfirmserviceregardlessofthelengthofthecontractandservicefrom,designated units of less than one year.Describe the nature oftheserviceinafootnoteforeachadjustment.
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
5.In column (e),identify the FERC Rate Schedule or Tariff Number,On separate lines,list all FERC rate schedules or contractdesignationsunderwhichservice,as identified in column (d),is provided.
6.Report receipt and delivery locations for all single contract path,"point to point"transmission service.In column (f),report thedesignationforthesubstation,or other appropriate identification for where energy was received as specified in the contract.In column
(g)report the designation for the substation,or other appropriate identification for where energy was delivered as specified in thecontract.
7.Report in column (h)the number of megawatts of billing demand that is specified in the firm transmission service contract.Demand
reported in column (h)must be in megawatts.Footnote any demand not stated on a megawatts basis and explain.
FERC Rate Point of Receipt Point of Delivery Billing TRANSFER OF ENERGY LineScheduleof(Subsatation or Other (Substation or Other Demand MegaWatt Hours |MegaWatt Hours No.Tariff Number Designation)Designation)(MW)Received Delivered(e)(f)(g)(h)(i)(j)
79 LaGrande,Oregon Various in Oregon 540 205,281 205,281 1
77 LaGrande,Oregon Various in Idaho 1,108,438 1,152,35E 2
WSPP Bannock Tap Vigilante Elect Coop 3
39 Minidoka,Idaho Various in Idaho 9,050 9,05C 4
89 Various in idaho LaGrande,Oregon 2,075 2,076 5
25 Various in Idaho LaGrande,Oregon 305,810 305,81C 6
4 Various in idaho LaGrande,Oregon 41,111 41,111 7
59 Various in Idaho Borah or Brady ID 962 962 8
85 Various in Idaho Borah or Brady,ID 3,221 3,221 9
93 Various in Idaho Midpoint,idaho 16,478 16,47E 10
81 Borah or Kinport,Id Various in Idaho 110,514 110,514 11
81 Various in Idaho Enterprise,Oregon 32,862 32,862 12
81 Enterprise,Oregon Various in Idaho 9,945 9,94E 13
11 Various in Idaho Borah or Brady,ID 223,505 223,50E 14
91 Various in Idaho Borah or Brady,ID 200 20C 15
9 Various in Idaho Midpoint,idaho 73,487 73,487 16
95 Various in Idaho LaGrande,Oregon 2,650 2,65C 17
943 2,933,262 2,973,489
FERC FORM NO.1 (ED.12-90)Page 329
This Page Intentionally Left Blank
Name of Respondent This Re ort Is.Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TRANsMISSION 01-ELECl RICI I Y POROl HERS (Account 456)(Continued)(including transactions reffered to as 'wheeling')
8.Report in column (i)and (j)the total megawatthours received and delivered.
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demandchargesrelatedtothebillingdemandreportedincolumn(h).In column (I),provide revenues from energy charges related to theamountofenergytransferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (11011)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or servicerendered.
10.Provide total amounts in column (i)through (n)as the last Line.Enter "TOTAL"in column (a)as the Last Line.The total amounts
in columns (i)and (j)must be reported as Transmission Received and Delivered on Page 401,Lines 16 and 17,respectively.
11.Footnote entries and provide explanations following all required data.
I
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Demand Charges |Energy Charges (Other Charges)Total Revenues ($)Line
($)($)($)I (k+l+m)No.(k)(l)(m)(n)
971,966 971,966 1
2,915,505 843,066 228,156 3,986,727 2
15,000 15,000 3
14,662 14,662 4
1,191,117 1,191,117 5
892,949 892,949 6
269,795 269,795 7
4,560 4,560 8
25,938 25,938 9
68,234 68,234 10
245,113 245,113 11
52,507 52,507 12
23,483 23,483 13
411,400 411,400 14
7,500 7,500 15
240,501 240,501 16
7,307 7,307 17
4,572,399 7,648,663 232,611 12,453,673
FERC FORM NO.1 (ED.12-90)Page 330
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
|RANSMidSION OF I-LEC1RICITY WOR UI HE RS (Account 456)(Including transactions referred to as 'wheeling')
1.Report all transmission of electricity,i.e.,wheeling,provided for other electric utilities,cooperatives,municipalities,other public
authorities,qualifying facilities,non-traditional utility suppliers and ultimate customers.
2.Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a),(b)and (c).
3.Report in column (a)the company or public authority that paid for the transmission service.Report in column (b)the company or
public authority that the energy was received from and in column (c)the company or public authority that the energy was delivered to.
Provide the full name of each company or public authority.Do not abbreviate or truncate name or use acronyms.Explain in a footnote
any ownership interest in or affiliation the respondent has with the entities listed in columns (a),(b)or (c)
4.In column(d)enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
LF -for Long-term firm transmission service."Long-term"means one year or longer and "firm"means that service cannot be interrupted
for economic reasons and is intended to remain reliable even under adverse conditions.For all transactions identified as LF,provide in
a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the
contract.
SF -for short-term firm transmission service.Use this category for all firm services,where the duration of each period of commitment
for service is less than one year.
Line Payment By Energy Received From Energy Delivered To Statistical
No (Company of Public Authority)(Company of Public Authority)(Company of Public Authority)Classifi-
(Footnote Affiliation)(Footnote Affiliation)(Footnote Affiliation)cation
(a)(b)(c)(d)
1 City of Seattle City of Seattle Bonneville Power Administration LF
2 Sierra Pacific Power Sierra Pacific Power Sierra Pacific Power LF
3 Sierra Pacific Power Sierra Pacific Power Sierra Pacific Power OS
4 United States Bureau of Indian Affairs Bonneville Power Administration Bureau of Indian Affairs LF
5 Cargill-Alliant Cargill-Alliant Bonneville Power Administation OS
6 Bonneville Power Administration Bonneville Power Company Bonneville Power Administration OS
7 Public Service Colorado Public Service Colorado Bonneville Power Administration OS
8 Constellation Power Source Constellation Power Source Avista OS
9 Public Service New Mexico Public Service New Mexico PacifiCorp OS
10 City of Seattle City of Seattle Bonneville Power Administration OS
11 Stasticial class OS indicates non-firm transmission services.
12 WSPP refers to westem system power pool.
13
14
15
16
17
TOTAL
FERC FORM NO.1 (ED.12-90)Page 328.1
Name of Respondent This Re ort Is.Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCornpany(2)A Resubmission 04/30/2001 Dec.31,
|RANSMISSION Ol-ELECTRICI IY FOR Ol HERS (Account 456)(Continued)(Including transactions reffered to as 'wheeling')
OS -for other service.Use this category only for those services which cannot be placed in the above-defined categories,such as allnonfirmserviceregardlessofthelengthofthecontractandservicefrom,designated units of less than one year.Describe the nature oftheserviceinafootnoteforeachadjustment.
AD -for out-of-period adjustment.Use this code for any accounting adjustments or "true-ups"for service provided in prior reportingyears.Provide an explanation in a footnote for each adjustment.
5.In column (e),identify the FERC Rate Schedule or TariffNumber,On separate lines,list all FERC rate schedules or contractdesignationsunderwhichservice,as identified in column (d),is provided.
6.Report receipt and delivery locations for all single contract path,"point to point"transmission service.In column (f),report thedesignationforthesubstation,or other appropriate identification for where energy was received as specified in the contract.In column
(g)report the designation for the substation,or other appropriate identification for where energy was delivered as specified in thecontract.
7.Report in column (h)the number of megawatts of billing demand that is specified in the firm transmission service contract.Demandreportedincolumn(h)must be in megawatts.Footnote any demand not stated on a megawatts basis and explain.
FERC Rate Point of Receipt Point of Delivery Billing TRANSFER OF ENERGY LineScheduleof(Subsatation or Other (Substation or Other Demand MegaWatt Hours MegaWatt Hours No.Tariff Number Designation)Designation)(MW)Received Delivered(e)(f)(g)(h)(i)(j)72 Lucky Peak,Idaho LaGrande,Oregon 403 67,342 63,64E 1
IWSPPMidpoint,Idaho Wells Nevada I 2
3 Various in Idaho Midpoint,Idaho 410,044 410,044 3
96 LaGrande,Oregon Various in Idaho 11,396 11,39E 4
62 Various in Idaho Hot Spring,Montana 8,383 8,382 5
12 Various in Idaho Hot Spring,Montant 50,813 50,812 6
81 Various in Idaho LaGrande,Oregon 236,449 236,44E 7
22 Various in idaho Divide,Idaho 2,676 2,67E 8 ,
61 Various in idaho Borah or Brady,ID 500 50C 9
47 Various in idaho LaGrande,Oregon 70 7C 10
11
12
13
14
15
16
17
943 2,933,262 2,973,488
FERC FORM NO.1 (ED.12-90)Page 329.1
This Page Intentionally Left Blank
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCornpany(2)A Resubmission 04/30/2001 Dec.31,
i RANSMISSION OF I-LEC iRICI I Y EOR 0 1 HERS (Account 456)(Continued)(including transactions reffered to as 'wheeling')
8.Report in column (i)and (j)the total megawatthours received and delivered.
9.In column (k)through (n),report the revenue amounts as shown on bills or vouchers.In column (k),provide revenues from demand
charges related to the billing demand reported in column (h).In column (I),provide revenues from energy charges related to the
amount of energy transferred.In column (m),provide the total revenues from all other charges on bills or vouchers rendered,including
out of period adjustments.Explain in a footnote all components of the amount shown in column (m).Report in column (n)the total
charge shown on bills rendered to the entity Listed in column (a).If no monetary settlement was made,enter zero (11011)in column
(n).Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service
rendered.
10.Provide total amounts in column (i)through (n)as the last Line.Enter "TOTAL"in column (a)as the Last Line.The total amounts
in columns (i)and (j)must be reported as Transmission Received and Delivered on Page 401,Lines 16 and 17,respectively.
11.Footnote entries and provide explanations following all required data.
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Demand Charges Energy Charges '(Other Charges)|Total Revenues ($)|Line
($)($)($)(k+l+m)No.
(k)(I)(m)(n)
566,280 4,455 570,735 1
47,250 47,250 2
1,039,355 1,039,355 3
56,398 56,398 4
117,562 117,562 5
99,082 99,082 6
1,985,546 1,985,546 7
103,614 103,614 8
2,692 2,692 9
2,680 2,680 10
11
12
13
14
15
16
17
4,572,399 7,648,663 232,611 12,453,673
FERC FORM NO.1 (ED.12-90)Page 330.1
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TRANSiv ISSION OF ELECTRICITY BY OTHERS (Account 565)(Including transactions referred to as "wheeling")
1.Report all transmission,i.e.,wheeling of electricity provided to respondent by other electric utilities,cooperatives,municipalities,or
other public authorities during the year.
2.In column (a)report each company or public authority that provide transmission service.Provide the full name of the company;
abbreviate if necessary,but do not truncate name or use acronyms.Explain in a footnote any ownership interest in or affiliation with the
transmission service provider.
3.Provide in column (a)subheadings and classify transmission service purchased form other utilities as:"Delivered Power to
Wheeler"or "Received Power from Wheeler."
4.Report in columns (b)and (c)the total Megawatthours received and delivered by the provider of the transmission service.
5.In columns (d)through (g),report expenses as shown on bills or vouchers rendered to the respondent.In column (d),provide
demand charges.In column (e),provide energy charges related to the amount of energy transferred.In column (f),provide the total of
all other charges on bills or vouchers rendered to the respondent,including any out of period adjustments.Explain in a footnote all
components of the amount shown in column (f).Report in column (9)the total charge shown on bills rendered to the respondent.If no
monetary settlement was made,enter zero ("0")column (g).Provide a footnote explaining the nature of the non-monetary settlement,
including the amount and type of energy or service rendered.
6.Enter "TOTAL"in column (a)as the last Line.Provide a total amount in columns (b)through (g)as the last Line.Energy provided by
the respondent for the wheeler's transmission tosses should be reported on the Electric Energy Account,Page 401.If the respondent
received power from the wheeler,energy provided to account for Losses should be reported on Line 19.Transmission By Others
Losses,on Page 401.Otherwise,Losses should be reported on line 27,Total Energy Losses,Page 401.
7.Footnote entries and provide explanations following all required data.
Line Name of Company or Public TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
No.Authority (Footnote Affiliations)Magawatt-Magawatt-Demand Energy Uther Total Cost ofNourshoursChargesChargesChargesTranssionReceivedDelivered($)($)($)(a)(b)(c)(d)(e)(f)
1 Received From:
2 Montana Power Company 109,766 109,766 195,400 10,805 206,205
3 Bad debt write-off 8,524 8,524
4
5
6
7
8
9
10
11
12
13
14
15
16
TOTAL 109,766 109,766 195,400 19,329 214,729
FERC FORM NO.1 (ED.12-90)Page 332
Name of Respondent This ort Is:Date of Report Year of Report
Idaho Power Company (1)An Original (Mo,Da,Yr)Dec 31 2000(2)A Resubmission 04/30/2001 '
MISCELLANEOUS GENERAL EXPENSES (Account 930.2)(ELECTRIC)
Line Description Amount
No.(a)(b)
1 Industry Association Dues 145,501
2 Nuclear Power Research Expenses
3 Other Experimental and General Research Expenses
4 Pub &Dist Info to Stkhldrs...expn servicing outstanding Securities 1,391,518
5 Oth Expn >=5,000 show purpose,recipient,amount.Group if <$5,000
6 Director fees and expenses:
7 Rotchford Barker 10,020
8 Robert D Bolinder 11,040
9 Roger Breezley 10,020
10 John Carley 11,040
11 Peter Johnson 16,293
12 Evelyn Loveless 14,420
13 Jack Lemiey 11,040
14 Jon Miller 36,000
15 Peter O'Neill 10,020
16 Robert Tinstman 10,020
17
18
19
20
21
22 Miscellaneous General Management:
23 Listing Services -New York Stock Exchange 34,358
24 Pacific Exchange 1,000
25
26 Memberships:
27 Associated Taxpayers of Idaho 20,493
28 National Hydropower Assocaition 15,916
29 Western Electric Power institute 51,991
30 Other (9)16,718
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL 1,817,408
FERC FORM NO.1 (ED.12-94)Page 335
This Page Intentionally Left Blank
Name of Respondent This R ort Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Account 403,404,4J5)
(Exœpt amortization of aquisition adjustments)
1.Report in Section A for the year the amounts for:(a)Depreciation Expense (Account 403);(b)Amortization of Limited-Term Electric
Plant (Account 404);and (c)Amortization of Other Electric Plant (Account 405).
2.Report in Section 8 the rates used to compute amortization charges for electric plant (Accounts 404 and 405).State the basis used
to compute charges and whether any changes have been made in the basis or rates used from the preceding report year.
3.Report all available information called for in Section C every fifth year beginning with report year 1971,reporting annually only
changes to columns (c)through (g)from the complete report of the preceding year.
Unless composite depreciation accounting for total depreciable plant is followed,list numerically in column (a)each plant subaccount,
account or functional classification,as appropriate,to which a rate is applied.Identify at the bottom of Section C the type of plant
included in any sub-account used.
In column (b)report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and
showing composite total.Indicate at the bottom of section C the manner in which column balances are obtained.If average balances,
state the method of averaging used.
For columns (c),(d),and (e)report available information for each plant subaccount,account or functional classification Listed in column
(a).If plant mortality studies are prepared to assist in estimating average service Lives,show in column (f)the type mortality curve
selected as most appropriate for the account and in column (g),if available,the weighted average remaining life of surviving plant.If
composite depreciation accounting is used,report available information called for in columns (b)through (g)on this basis.
4.If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates,state at
the bottom of section C the amounts and nature of the provisions and the plant items to which related.
A.Summary of Depreciation and Amortization Charges
Line 'Decreciation Amortization of I Amortization of |
No Functional Classification Expense Limited Term Elec-Other Electric Total(Account 403)tric Plant (Acc 404)Plant (Acc 405)(a)(b)(c)(d)(e)
1 Intangible Plant 3,965,743 3,965,743
2 Steam Production Plant 22,734,083 22,734,083
3 Nuclear Production Plant
4 Hydraulic Production Plant-Conventional 11,916,932 312 11,917,244
5 Hydraulic Production Plant-Pumped Storage
6 Other Production Plant 16,263 16,263
7 Transmission Plant 9,330,368 9,330.368
8 Distribution Plant 26,653,029 26,653,029
9 General Plant 5,753,786 5,753,786
10 Common Plant-Electric
11 TOTAL 76,404,461 3,966,055 80,370.516
B.Basis for Amortiza ion Charges
Account 404
Balance to be 2000 Balance to be Remaining months of
amortized amortization amortized 12/31/00 amortization 12/31/00
(1)92,284 15,372 76,912 55
(2)36,000 12,000 24,000 24
(3)2,323,837 105,432 8,043,027 348
(4)16,018,559 3,820,999 30,572,741
(5)308,342 12,252 296,090 290
Total 3,966,055
(1)TE Roach development archaeological study,FERC &Oregon license costs (temination date July 31,2005).
(2)Shoshone-Bannock Tribe licnese and use agreement (termination date December 31,2023).
(3)Middle snake relicensing costs (termination date December 31,2030).
(4)Computer software packages (amortized over a 60 month period from date of purchase).
FERC FORM NO.1 (ED.12-88)Page 336
Name of Respondent This R ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Line Deprectable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining
(In Thousands)Life (Percent)(Percent)Type Life
(a)(b)(c)(d)(e)(t)(q)
12 310.00 196 45.00 2.20 Life Span 30.00
13 311.00 128,631 39.00 -17.00 2.97 Life Span 28.30
14 312.10 81,327 41.00 -21.00 3.45 Life Span 28.90
15 312.20 347,293 39.00 -17.00 2.99 Life Span 27.90
16 312.30 4,116 25.00 5.00 3.97 Life Span 24.10
17 314.00 106,538 39.00 -18.00 3.23 Life Span 28.50
18 315.00 61,391 39.00 -16.00 3.01 Life Span 27.90
19 316.00 10,193 39.00 -16.00 4.17 Life Span 23.40
20 316.40 167 7.00 25.00 11.00 R2.5 4.20
21 316.50 17 7.00 15.00 12.53 R2.5 4.70
22 316.70 21 14.00 30.00 5.05 RO.5 11.40
23 316.80 2,181 20.00 40.00 3.05 R1.0 14.30
24 Subtotal Steam 742,071
25 331.00 125,974 75.00 -19.00 1.88 Life Span 45.60
26 332.10 19,461 80.00 1.56 Life Span 44.00
27 332.20 217,428 76.00 -29.00 2.47 Life Span 41.50
28 332.30 3,899 39.00 6.65 Life Span 38.70
29 333.00 181,257 74.00 1.55 Life Span 45.60
30 334.00 34,465 74.00 -10.00 1.93 Life Span 40.60
31 335.00 13,216 75.00 -5.00 1.58 life Span 46.50
32 336.00 6,934 77.00 1.53 Life Span 45.30
33 Subtotal Hydro 602,634
34 341.00 12 30.00 8.43 Life Span 9.00
35 342.00 61 30.00 8.92 Life Span 9.00
36 343.00 26.00 Life Span 9.00
37 344.00 522 30.00 1.78 Life Span 9.00
38 345.00 37 30.00 4.10 Life Span 9.00
39 346.00 30.00 Life Span 9.00
40 Subtotal Other 632
41 350.00 10,802 70.00 1.45 R5.0 51.70
42 352.00 22,427 40.00 -25.00 3.23 R5.0 22.60
43 353.00 167,306 40.00 5.00 2.43 R4.0 26.40
44 354.00 52,620 60.00 1.69 L4.0 45.70
45 355.00 68,214 45.00 -25.00 2.85 R4.0 27.70
46 356.00 87,551 50.00 10.00 1.85 R5.0 30.60
47 359.00 321 70.00 1.52 R5.0 29.70
48 Subtotal Transmission 409,241
49 361.00 11,681 45.00 -25.00 2.83 R2.0 31.30
50 362.00 95,508 40.00 5.00 2.43 R2.5 26.00
FERC FORM NO.1 (ED.12-95)Page 337
Name of Respondent This Report Is:Date of Report Year of Report(1)p An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)
C.Factors Used in Estimating Depreciation Charges
Line i Depreciable Estimated Net Applied Mortality Average
No Account No.Plant Base Avg.Service Salvage Depr.rates Curve Remaining(In Thousands)Life (Percent)(Percent).T e Life(a)(b)(c)(d)(e)(q)
12 364.00 158,378 35.00 -15.00 3.35 L2.0 24.50
13 365.00 84,014 45.00 -10.00 2.48 R1.0 34.00
14 366.00 25,338 50.00 2.02 R2.5 40.60
15 367.00 111,369 30.00 I 3.38 R4.0 22.00
16 368.00 242,212 25.00 5.00 3.92 R4.0 15.30
17 369.00 38,604 25.00 -20.00 4.94 R5.0 14.90
18 370.00 36,864 35.00 2.90 L2.0 25.40
19 371.10 387 10.00 30.00 7.00 LO 9.00
20 371.20 1,646 13.00 7.89 LO 8.40
21 373.00 3,665 25.00 -15.00 4.70 L2.0 17.10
22 Subtotal Distribution 809,666
23 390.11 23,681 60.00 1.68 R4.0 59.50
24 390.12 24,929 45.00 2.22 R1.5 36.50
25 390.20 4,218 20.00 -5.00 5.37 R3.0 13.50
26 391.10 9,086 20.00 5.00 4.82 RO.5 15.00
27 391.20 23,860 8.00 5.00 12.21 R2.0 4.50
28 391.21 4,370 8.00 5.00 12.21 R2.0 4.50
29 392.10 155 8.00 15.00 10.76 RO.5 5.50
30 392.40 12,179 7.00 25.00 11.03 R2.5 4.20
31 392.50 200 7.00 15.00 12.53 R2.5 4.70
32 392.60 15,590 14.00 30.00 5.12 RO.5 9.50
33 392.70 2,876 14.00 30.00 5.05 RO.5 11.40
34 392.90 2,678 17.00 30.00 4.20 R1.0 11.90
35 393.00 845 25.00 15.00 3.44 RO.5 19.10
36 394.00 2,879 20.00 10.00 4.60 L3.0 13.30
37 395.00 7,163 20.00 5.00 4.83 R5.0 13.90
38 396.00 5,608 20.00 40.00 3.05 R1.0 14.30
39 397.10 5,304 25.00 -10.00 4.46 L2.0 19.40
40 397.20 6,782 20.00 5.14 L3.0 12.00
41 397.30 2,165 20.00 5.16 L4.0 11.60
42 397.40 639 20.00 -10.00 5.50 L2.0 19.50
43 398.00 1,794 17.00 5.00 5.72 L1.5 11.50
44 Subtotal General 157,001
45 Total Plant 2,721,245
46
47
48
49
50
FERC FORM NO.1 (ED.12-95)Page 337.1
This Page Intentionally Left Blank
l Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
PARTICULARS CONCERNING CERTAIN INCOME DEDUCTIONS AND INTEREST CHARGES ACCOUNTS
Report the information specified below,in the order given,for the respective income deduction and interest charges account.Provide a subheading for
each account and a total for the account.Additional columns may be added if deemed appropriate with respect to any account.
(a)Miscellaneous Amortization (Account 425):Describe the nature of items included in this account,the contra account charged,the total of
amortization charges for the year,and the period of amortization.
(b)Miscellaneous Income Deductions:Report the nature,payee,and amount of other income deductions for the year as required by Accounts 426.1,Donations;426.2,Life Insurance;426.3,Penalties;426.4,Expenditures for Certain Civic Political and Related Activities;and 426.5,Other Deductions,of
the Uniform System of Accounts.Amounts of less than 5%of each account total for the year (or $1,000,whichever is greater)may be grouped by
classes within the above accounts.
(c)Interest on Debt to Associated Companies (Account 430)--For each associated company to which interest on debt was incurred during the year,
indicate the amount and interest rate respectively for (a)advances on notes,(b)advances on open account,(c)notes payable,(d)accounts payable,
and (e)other debt,and total interest.Explain the nature of other debt on which interest was incurred during the year.
(d)Other Interest Expense (Account 431)--Report particulars (details)including the amount and interest rate for other interest charges incurred
during the year.
Line Item AmountNo.(a)(b)
1 Account 425 -Miscellaneous Amortization -None
2
3 Account 426.1 -Donations
4 Idaho State University 100,000
5 University of Idaho 114,000
6 other donations each under 5%of account 756,728
7 Total 426.1 970,728
8
9 Account 426.2 -Life insurance -1,420,720
10 Total 426.2 -1,420,720
11
12 Account 426.3 -Penalities -None
13
14 Account 426.4 -Civic &Political Expenditures
15 Legislative Task Force 50,000
16 Lobbying expenses 328,123
17 other political exepnditures under 5%of account 99,120
18 Total 426.4 477,243
19
20 Account 426.5 -Other Deductions
21 Security Plan 3,041,000
22 Total 426.5 3,041,000
23
24 Account 430 -Interest on debt to Assoc Companies
25 Idaho Energy Resources Company 5.82%to 6.84%348,980
26 other interest under 5%of account 672
27 Total 430 349,652
28
29 Account 431 -Other interest Expense
30 Deferred director fees 10.87%to 11.41%271,668
31 Short -Term borrowing 5.82%to 6.84%1,475,588
32 Meridian buyout -9.199%146,524
33 Other items each under 5%of account 934,485
34 Total 431 2,828,265
35
36
37
38
39
40
41
FERC FORM NO.1 (ED.12-87)Page 340
Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
REGULATORY COMMISSION EXPENSES
1.Report particulars (details)of regulatory commission expenses incurred during the current year (or incurred in previous years,if
being amortized)relating to format cases before a regulatory body,or cases in which such a body was a party.
2.Report in columns (b)and (c),only the current year's expenses that are not deferred and the current year's amortization of amounts
deferred in previous years.
.Line Description Assessed by Expenses Total .Deferred
No.(Furnish name of regulatory commission or body the Regulatory Expense for in Account
docket or case number and a description of the case)Commission Utility Curbrent ear Begir11nrig3o Year
(a)(b)(c)(d)(e)
1 Federal Energy Regulatory Commission:
2 Annual administrative charges 3,869,479 3,869,479
3
4 General Regulatory Expenses:
5 Other Expenses 110,839 110,839
6
7 Regulatory Commission Expenses -Idaho
8 Other Expenses -202 -202
9
10 Regulatory Commission Expenses -Oregon
11 Oregon Hydro -Fees amortization 158,505 158,505
12 General Regulatory Expenses 11,712 11,712
13
14 Regulatory Commission Expenses -Nevada
15 General Regulatory Expenses 104,603 104,603
16 Other Expenses 5,503 5,503
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL 4,027,984 232,455 4,260,439
FERC FORM NO.1 (ED.12-96)Page 350
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
REGULATORY COMMISSION EXPENSES (Continued)
3.Show in column (k)any expenses incurred in prior years which are being amortized.List in column (a)the period of amortization.
4.List in column (f),(g),and (h)expenses incurred during year which were charged currently to income,plant,or other accounts.
5.Minor items (less than $25,000)may be grouped.
EXPENSES INCURRED DURING YEAR AMORTIZED DURING YEAR
CURRENTLY CHARGED TO Deferred to Contra Amount Deferred in LineDepartmentAcguntAmountAccount182.3 Account Accnodont 8a2.3 No.
(f)(9)(h)(i)(j)(k)(l)
1
Electric 928 3,869,479 2
3
4
Electric 928 110,839 5
6
7
Electric 928 -202 8
9
10 .
Electric 928 158,505 11
Electric 928 11,712 12
13
14
Electric 928 104,603 15
Electric 928 5,503 16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
4,260,439 46
FERC FORM NO.1 (ED.12-96)Page 351
l Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)Idaho Power Company Dec.31,2000
(2)A Resubmission 04/30/2001
RESEARCH,DEVELOPMENT,AND DEMONSTRATION ACTIVITIES
1.Describe and show below costs incurred and accounts charged during the year for technological research,development,and demonstration (R,D &
D)project initiated,continued or concluded during the year.Report also support given to others during the year for jointly-sponsored projects.(Identify
recipient regardless of affiliation.)For any R,D &D work carried with others,show separately the respondent's cost for the year and cost chargeable to
others (See definition of research,development,and demonstration in Uniform System of Accounts).
2.Indicate in column (a)the applicable classification,as shown below:
Classifications:
A.Electric R,D &D Performed Internally:(3)Transmission
(1)Generation a.Overhead
a.hydroelectric b.Underground
i.Recreation fish and wildlife (4)Distribution
ii Other hydroelectric (5)Environment (other than equipment)
b.Fossil-fuel steam (6)Other (Classify and include items in excess of $5,000.)
c.Internal combustion or gas turbine (7)Total Cost Incurred
d.Nuclear B.Electric,R,D &D Performed Externally:
e.Unconventional generation (1)Research Support to the electrical Research Council or the Electric
f.Siting and heat rejection Power Research Institute
Line Classification Description
No.(a)(b)
1 Electric Power Research Institute -Membership dues
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
FERC FORM NO.1 (ED.12-87)Page 352
Name of Respondent This Re ort is:Date of Report Year of Report
Idaho Power Company
(R um ssion
30D2a001 Dec.31,2000
RESEARCH,DEVELOPMENT,AND DEMONSTRATION ACTIVITIES (Continued)
(2)Research Support to Edison Electric Institute
(3)Research Support to Nuclear Power Groups
(4)Research Support to Others (Classify)
(5)Total Cost incurred
3.Include in column (c)all R,D &D items performed internally and in column (d)those items performed outside the company costing $5,000 or more,
briefly describing the specific area of R,D &D (such as safety,corrosion control,pollution,automation,measurement,insulation,type of appliance,etc.).
Group items under $5,000 by classifications and indicate the number of items grouped.Under Other,(A (6)and B (4))classify items by type of R,D &D
activity.
4.Show in column (e)the account number charged with expenses during the year or the account to which amounts were capitalized during the year,
listing Account 107,Construction Work in Progress,first.Show in column (f)the amounts related to the account charged in column (e)
5.Show in column (g)the total unamortized accumulating of costs of projects.This total must equal the balance in Account 188,Research,
Development,and Demonstration Expenditures,Outstanding at the end of the year.
6.If costs have not been segregated for R,D &D activities or projects,submit estimates for columns (c),(d),and (f)with such amounts identified by
"Est."
7.Report separately research and related testing facilities operated by the respondent.
Costs Incurred Internally Costs Incurred Externally AMOUNTS CHARGED IN CURRENT YEAR Unamortized LineCurrenYearCurrentYearAccountAmountAccumulationNo.(d)(e)(f)(9)
126,722 930 126,722 1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
FERC FORM NO.1 (ED.12-87)Page 353
\Name of Respondent This Re ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
DISTRIBUTION OF SALARIES AND NAGES
Report below the distribution of total salaries and wages for the year.Segregate amounts originally charged to clearing accounts to
Utility Departments,Construction,Plant Removals,and Other Accounts,and enter such amounts in the appropriate lines and columns
provided.In determining this segregation of salaries and wages originally charged to clearing accounts,a method of approximation
giving substantially correct results may be used.
1 Electric
Classification
2 Operation
3 Production 6,225,02
4 Transmission 3,918,388
5 Distribution 13,431,377
6 Customer Accounts 7,457,082
7 Customer Service and Informational 2,759,498
8 Sales
9 Administrative and General 26,869,116
10 TOTAL Operation (Enter Total of lines 3 thru 9)60,660,488
11 Maintenance
12 Production 5,021,774
13 Transmission 2,061,637
14 Distribution 6,813,973
15 Administrative and General 276,725
16 TOTAL Maint.(Total of lines 12 thru 15)14,174,10
17 Total Operation and Maintenance
18 Production (Enter Total of lines 3 and 12)11,246,801
19 Transmission (Enter Total of lines 4 and 13)5,980,02
20 Distribution (Enter Total of lines 5 and 14)20,245,350 WÑ
21 Customer Accounts (Transcribe from line 6)7,457,082 NN
22 Customer Service and informational (Transcribe from line 7)2,759,498
23 Sales (Transcribe from line 8)
24 Administrative and General (Enter Total of lines 9 and 15)27,145,841
25 TOTAL Oper.and Maint.(Total of lines 18 thru 24)74,834,597 3,245,933 78 080,530
26 Gas
27 Operation
28 Production-Manufactured Gas
29 Production-Nat.Gas (Including Expl.and Dev.)
30 Other Gas Supply
31 Storage,LNG Terminaling and Processing
32 Transmission
33 Distribution
34 Customer Accounts
35 Customer Serviœ and Informational
36 Sales
37 Administrative and General
38 TOTAL Operation (Enter Total of lines 28 thru 37)
39 Maintenance
40 Production-Manufactured Gas
41 Production-Natural Gas
42 Other Gas Supply
43 Storage,LNG Terminaling and Processing
44 Transmission
45 Distribution
46 Administrative and General
47 TOTAL Maint.(Enter Total of lines 40 thru 46)
FERC FORM NO.1 (ED.12-88)Page 354
Name of Respondent This R ort is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Idaho Power Company Dec.31,2000(2)A Resubmission 04/30/2001
DISTRIBUTION OF SALARIES AND WAGES (Continued)
Total Operation and
MaintClaassification
49 Production-Manufactured Gas (Enter Total of lines 28 and 40)
50 Production-Natural Gas (Including Expl.and Dev.)(Total lines 29,
51 Other Gas Supply (Enter Total of lines 30 and 42)
52 Storage,LNG Terminaling and Processing (Total of lines 31 thru
53 Transmission (Lines 32 and 44)
54 Distribution (Lines 33 and 45)
55 Customer Accounts (Line 34)
56 Customer Service and Informational (Line 35)
57 Sales (Line 36)
58 Administrative and General (Lines 37 and 46)
59 TOTAL Operation and Maint.(Total of lines 49 thru 58)
60 Other Utility Departments
61 Operation and Maintenance
62 TOTAL All Utility Dept.(Total of lines 25,59,and 61)74,834,597 3,245,933 78 080,530
63 Utility Plant
64 Construction (By Utility Departments)
65 Electric Plant 28,680,224 28,680,224
66 Gas Plant
67 Other
68 TOTAL Construction (Total of lines 65 thru 67)28,680,224 28,680,224
69 Plant Removal (By Utility Departments)e,...AZÀ
70 Electric Plant
71 Gas Plant
72 Other
73 TOTAL Plant Removal (Total of lines 70 thru 72)
74 Other Accounts (Specify):
75 Misc Deferred and Regulatory assets 776,641 776,641
76 Paid absences 10,737,317 10,737,317
77 Expenses of nonutility operations 1,510,433 1,510,433
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95 TOTAL Other Accounts 13,024,391 13,024,391
96 TOTAL SALARIES AND WAGES 116,539,212 3,245,933 119,785,145
FERC FORM NO.1 (ED.12-88)Page 355
Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ELECTRIC ENERGYACCOUNT
Report below the information called for concerning the disposition of electric energy generated,purchased,exchanged and wheeled during the year.
Line Item MegaWatt Hours Line Item MegaWatt Hours
No.No.I
(a)(b)(a)(b)
1 SOURCES OF ENERGY 21 DISPOSITION OF ENERGY
2 Generation (Excluding Station Use):22 Sales to Ultimate Consumers (including 14,598,388
3 Steam 7,698,944 Interdepartmental Sales)
4 Nuclear 23 Requirements Sales for Resale (See 51,371
5 Hydro-Conventional 8,499,684 instruction 4,page 311.)
6 Hydro-Pumped Storage 24 Non-Requirements Sales for Resale (See 4,477,429
7 Other 2,792 instruction 4,page 311.)
8 Less Energy for Pumping 25 Energy Furnished Without Charge
9 Net Generation (Enter Total of lines 3 16,201,420 26 Energy Used by the Company (Electric
through 8)Dept Only,Excluding Station Use)
10 Purchases 4,299,948 27 Total Energy Losses 1,261,544
11 Power Exchanges:28 TOTAL (Enter Total of Lines 22 Through 20,388,732
12 Received 975,808 27)(MUST EQUAL LINE 20)
13 Delivered 1,048,217
14 Net Exchanges (Line 12 minus line 13)-72,409
15 Transmission For Other (Wheeling)
16 Received 2,933,262
17 Delivered 2,973,489
18 Net Transmission for Other (Line 16 minus -40,227
line 17)
19 Transmission By Others Losses
20 TOTAL (Enter Total of lines 9,10,14,18 20,388,732
and 19)
FERC FORM NO.1 (ED.12-90)Page 401a
Name of Respondent This Report is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000,Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,
MONTHLY PEAKS AND OUTPUT
1.If the respondent has two or more power systems which are not physically integrated,furnish the required information for each non-integrated system.2.Report in column (b)the system's energy output for each month such that the total on Line 41 matches the total on Line 20.3.Report in column (c)a monthly breakdown of the Non-Requirements Sales For Resale reported on Line 24.include in the monthly amounts anyenergylossesassociatedwiththesalessothatthetotalonLine41exceedstheamountonLine24bytheamountoflossesincurred(or estimated)inmakingtheNon-Requirements Sales for Resale.
4.Report in column (d)the system's monthly maximum megawatt Load (60-minute integration)associated with the net energy for the system defined asthedifferencebetweencolumns(b)and (c)
5.Report in columns (e)and (f)the specified information for each monthly peak load reported in column (d).
NAME OF SYSTEM:
Line Monthly Non-Requirments MONTHLY PEAKSalesforResale&.No Month Total Monthly Energy Associated Losses Megawatts (See Instr.4)Day of Month Hour
(a)(b)(c)(d)(e)(f)
29 January 1,800,500 460,817 2,266 6 9 AM
30 February 1,577,869 428,490 2,132 3 8 AM
31 March 1,822,332 643,365 1,978 10 8 AM
32 April 1,919,411 791,457 2,000 27 4 PM
33 May 1,686,089 338,590 2,253 23 10 PM
34 June 1,818,574 220,719 2,799 29 8 PM
35 July 1,970,723 259,142 2,919 12 5 PM
36 August 1,849,104 284,891 2,746 2 5 PM
37 September 1,687,441 472,823 2,418 14 7 PM
38 October 1,361,903 287,617 1,898 4 8 AM
39 November 1,394,033 131,368 2,179 17 8 AM
40 December 1,500,753 158,150 2,091 8 8 PM
41 TOTAL 20,388,732 4,477,429
FERC FORM NO.1 (ED.12-90)Page 401b
Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)
1.Report data for plant in Service only.2.Large plants are steam plants with installed capacity (name plate rating)of 25,000 Kw or more.Report in
this page gas-turbine and internal combustion plants of 10,000 Kw or more,and nuclear plants.3.Indicate by a footnote any plant leased or operated
as a joint facility.4.If net peak demand for 60 minutes is not available,give data which is available,specifying period.5.If any employees attend
more than one plant,report on line 11 the approximate average number of employees assignable to each plant.6.If gas is used and purchased on a
therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct.7.Quantities of fuel burned (Line 37)and average cost
per unit of fuel burned (Line 40)must be consistent with charges to expense accounts 501 and 547 (Line 41)as show on Line 19.8.If more than one
fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
Line Item Plant Plant
No.Name:Jim Bridger Name:Boardman
(a)(b)(c)
1 Kind of Plant (Internal Comb,Gas Turb,Nuclear Steam Steam
2 Type of Constr (Conventional,Outdoor,Boiler,etc)Semi-Outdoor Boiler Conventional
3 Year Originally Constructed 1974 1980
4 Year Last Unit was Installed 1979 1980
5 Total Installed Cap (Max Gen Name Plate Ratings-MW)709.62 56.05
6 Net Peak Demand on Plant -MW (60 minutes)712 60
7 Plant Hours Connected to Load 8784 6908
8 Net Continuous Plant Capability (Megawatts)O 0
9 When Not Limited by Condenser Water 0 0
10 When Limited by Condenser Water 0 0
11 Average Number of Employees O 0
12 Net Generation,Exclusive of Plant Use -KWh 5400033000 353514000
13 Cost of Plant:Land and Land Rights 487488 106610
14 Structures and improvements 61786161 13427972
15 Equipment Costs 322812938 48400489
16 Total Cost 385086587 61935071
17 Cost per KW of Installed Capacity (line 5)542.6659 1104.9968
18 Production Expenses:Oper,Supv,&Engr 1089072 535210
19 Fuel 59220094 4355665
20 Coolants and Water (Nuclear Plants Only)0 0
21 Steam Expenses 3943179 0
22 Steam From Other Sources O O
23 Steam Transferred (Cr)0 0
24 Electric Expenses O O
25 Misc Steam (or Nuclear)Power Expenses 7422656 171178
26 Rents 121130 425673
27 Allowances 0 1403472
28 Maintenance Supervision and Engineering 1254 0
29 Maintenance of Structures O 0
30 Maintenance of Boiler (or reactor)Plant 3354892 0
31 Maintenance of Electric Plant 1168686 0
32 Maintenance of Misc Steam (or Nuclear)Plant 2596961 16247
33 Total Production Expenses 78917924 6907445
34 Expenses per Net KWh 0.0146 0.0195
35 Fuel:Kind (Coal,Gas,Oil,or Nuclear)Coal Oil Coal Oil
36 Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate)Tons Barrels Tons Barrels
37 Quantity (units)of Fuel Burned 3052668 0 7474 208785 0 1086
38 Avg Heat Cont -Fuel Burned (btulindicate if nuclear)9272 0 140000 8688 0 138800
39 Avg Cost of Fuellunit,as Delvd f.o.b.during year 19.142 0.000 42.591 19.072 0.000 43.779
40 Average Cost of Fuel per Unit Burned 19.130 0.000 36.726 19.650 0.000 37.322
41 Average Cost of Fuel Burned per Million BTU 1.050 0.000 6.250 1.170 0.000 6.400
42 Average Cost of Fuel Burned per KWh Net Gen 0.000 0.011 0.000 0.000 0.012 0.000
43 Average BTU per KWh Net Generation 0.000 10492.000 0.000 0.000 10280.000 0.000
FERC FORM NO.1 (ED.12-95)Page 402
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued)
9.Items under Cost of Plant are based on U.S.of A.Accounts.Production expenses do not include Purchased Power,System Control and LoadDispatching,and Other Expenses Classified as Other Power Supply Expenses.10.For IC and GT plants,report Operating Expenses,Account Nos.
547 and 549 on Line 24 "Electric Expenses,"and Maintenance Account Nos.553 and 554 on Line 31,"Maintenance of Electric Plant."Indicate plantsdesignedforpeakloadservice.Designate automatically operated plants.11.For a plant equipped with combinations of fossil fuel steam,nuclear
steam,hydro,internal combustion or gas-turbine equipment,report each as a separate plant.However,if a gas-turbine unit functions in a combined
cycle operation with a conventional steam unit,include the gas-turbine with the steam plant.12.If a nuclear power generating plant,briefly explain by
footnote (a)accounting method for cost of power generated including any excess costs attributed to research and development;(b)types of cost units
used for the various components of fuel cost;and (c)any other informative data concerning plant type fuel used,fuel enrichment type and quantity forthereportperiodandotherphysicalandoperatingcharacteristicsofplant.
Plant Plant Plant LineName:Valmy Name:Name:No.
(d)(e)(f)
Steam 1
Outdoor 2
1981 3
1985 4
260.65 0.00 0.00 5
270 0 0 6
8730 0 0 7
0 0 0 8
0 0 0 9
0 0 0 10
0 0 0 11
1945392000 0 0 12
681105 0 0 13
53416392 0 0 14
241874596 0 0 15
295972093 0 0 16
1135.5154 0.0000 0.0000 17
290494 0 0 18
30359031 0 0 19
0 0 0 20
1928933 0 0 21
0 0 0 22
0 0 0 23
1359746 0 0 24
3595150 0 0 25
42122 0 0 26
0 0 0 27
236926 0 0 28
297833 0 0 29
3404250 0 0 30
647466 0 0 31
145591 0 0 32
42307542 0 0 33
0.0217 0.0000 0.0000 34
Coal Oil 35
Tons Barrels 36
886752 0 6364 0 0 0 0 0 0 37
10407 0 138778 0 0 0 0 0 0 38
34.342 0.000 41.469 0.000 0.000 0.000 0.000 0.000 0.000 39
33.230 0.000 37.314 0.000 0.000 0.000 0.000 0.000 0.000 40
1.630 0.000 6.400 0.000 0.000 0.000 0.000 0.000 0.000 41
0.000 0.017 0.000 0.000 0.000 0.000 0.000 0.000 0.000 42
0.000 9560.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 43
FERC FORM NO.1 (ED.12-88)Page 403
This Page Intentionally Left Blank
NameofRespondent ThisRepodis:DateofRepod YearofRepon(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTEDATA
Schedule Page:402 Line No.:3 Column:b
This footnote applies to lines 3 and 4.The Jim Bridger PowerPlantconsistsoffourequalunitsconstructedjointlybyIdahoPowerCompanyandPacificPowerandLightCompany,with Idahoowning1/3 and PacifiCorp owning 2/3.Unit #1 was placed incommercialoperationNovember30,1974,Unit #2 December 1,1975,Unit #3 September 1,1976 and Unit #4 November 29,1979.Schedule Page:402 Line No.:3 Column:c
This footnote applies to lines 3 and 4.The Boardman plantconsistsofoneunitconstructedjointlybyPortlandGeneralElectricCompany,Idaho Power Company and Pacific NorthwestGeneratingCompany,with Idaho Power Company owning 10%.TheunitwasplacedincommercialoperationAugust3,1980.Schedule Page:402 Line No.:3 Column:d
This footnote applies to lines 3 and 4.The Valmy plant consistsoftwounitsconstructedjointlybySierraPacificPowerCompanyandIdahoPowerCompany,with Sierra owning 1/2 and Idaho owning1/2.Unit #1 was placed in commercial operation December 11,1981andUnit#2 May 21,1985.
Schedule Page:402 Line No.:5 Column:b
This footnote applies to line 5 and lines 12 through 43.Information reflects Idaho Power Company's share as explainedinnoteforline3page402columnB.
Schedule Page:402 Line No.:5 Column:c
This footnote applies to line 5 and lines 12 through 43.Information reflects Idaho Power Company's share as explainedinnoteonline3page402columnC
Schedule Page:402 Line No.:5 Column:d
This footnote applies to line 5 and lines 12 through 43.Information reflects Idaho Power Company's share as explainedinnoteforline3page403columnD.
Schedule Page:402 Line No.:9 Column:b
This footnote applies to lines 9,10 and 11.PacifiCorp
as operator of the plant will report thisinformation.
Schedule Page:402 Line No.:9 Column:c
This footnote applies to lines 9,10 and 11.Portland GeneralElectricCompany,as operator will report this information.Schedule Page:402 Line No.:9 Column:d
This footnote applies to lines 9,10 and 11.Sierra PacificPower,as operator of the plant,will report this information.
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Report is:Date of Report Year of Report |(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)
1.Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings)
2.If any plant is leased,operated under a license from the Federal Energy Regulatory Commission,or operated as a joint facility,indicate such facts in
a footnote.If licensed project,give project number.
3.If net peak demand for 60 minutes is not available,give that which is available specifying period.
4.If a group of employees attends more than one generating plan,report on line 11 the approximate average number of employees assignable to each
plant.
Line item FERC Licensed Project No.2736 FERC Licensed Project No.1975
No-Plant Name:American Falls Plant Name:Bliss
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Run-of-River Run-of-River
2 Plant Construction type (Conventional or Outdoor)Outdoor Outdoor
3 Year Originally Constructed 1978 1949
4 Year Last Unit was Installed 1978 1950
5 Total installed cap (Gen name plate Rating in MW)92.30 75.00
6 Net Peak Demand on Plant-Megawatts (60 minutes)97 76
7 Plant Hours Connect to Load 7,209 8,773
8 Net Plant Capability (in megawatts)0 0
9 (a)Under Most Favorable Oper Conditions 112 80
10 (b)Under the Most Adverse Oper Conditions O 76
11 Average Number of Employees 3 4
12 Net Generation,Exclusive of Plant Use -Kwh 386,132,000 405,623,000
13 Cost of Plant 0 0
14 Land and Land Rights 875,615 463,556
15 Structures and Improvements 11,798,887 620,442
16 Reservoirs,Dams,and Waterways 4,242,904 7,428,168
17 Equipment Costs 30,777,287 6,384,014
18 Roads,Railroads,and Bridges 306,333 486,477
19 TOTAL cost (Total of 14 thru 18)48,001,026 15,382,657
20 Cost per KW of Installed Capacity (line 5)520.0545 205.1021
21 Production Expenses 0 0
22 Operation Supervision and Engineering 152,270 151,806
23 Water for Power 892,675 221,559
24 Hydraulic Expenses 77,669 80,416
25 Electric Expenses 32,040 10,326
26 Misc Hydraulic Power Generation Expenses 113,963 108,337
27 Rents 128 0
28 Maintenance Supervision and Engineering 33,284 83,951
29 Maintenance of Structures 125,975 78,313
30 Maintenance of Reservoirs,Dams,and Waterways 0 205,197
31 Maintenance of Electric Plant 103,657 220,810
32 Maintenance of Misc Hydraulic Plant 59,929 187,947
33 Total Production Expenses (total 22 thru 32)1,591,590 1,348,662
34 Expenses per net KWh 0.0041 0.0033
FERC FORM NO.1 (ED.12-88)Page 406
Name of Respondent This Report Is:Date of Report Year of Report(1)g An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued)
5.The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts.Production ExpensesdonotincludePurchasedPower,System control and Load Dispatching,and Other Expenses classified as "Other Power Supply Expenses."
6.Report as a separate plant any plant equipped with combinations of steam,hydro,internal combustion engine,or gas turbine equipment.
FERC Licensed Project No.1971 FERC Licensed Project No.2848 FERC Licensed Project No.1971 LinePlantName:Brownlee Plant Name:Cascade Plant Name:Oxbow No.(d)(e)(f)
Storage Run-of-River Storage 1
Outdoor Outdoor'Outdoor 2
1958 1983 1961 3
1980 1984 1961 4
585.40 12.42 190.00 5
657 14 219 6
8,784 8,784 8,774 7
0 0 0 8
728 14 220 9
617 0 220 10
6 2 5 11
2,508,111,000 47,477,000 1,087,536,000 12
0 0 0 13
5,654,942 82,142 866,938 14
29,807,067 7,376,223 9,597,999 15
64,986,969 3,145,630 30,070,871 16
49,431,771 12,820,154 14,529,445 17
518,444 122,668 565,842 18
150,399,193 23,546,817 55,631,095 19
256.9170 1,895.8790 292.7952 20
0 0 0 21
543,089 114,797 290,309 22
319,283 74,654 93,046 23
347,162 31,671 181,384 24
242,119 47,042 145,588 25
202,908 67,149 149,277 26
194,986 93 33,492 27
199,061 12,879 76,239 28
211,037 34,296 165,205 29
375,381 2,902 0 30
454,639 36,730 241,347 31
426,012 43,545 254,391 32
3,515,677 465,758 1,630,278 33
0.0014 0.0098 0.0015 34
FERC FORM NO.1 (ED.12-88)Page 407
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)
1.Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings)
2.If any plant is leased,operated under a license from the Federal Energy Regulatory Commission,or operated as a joint facility,indicate such facts in
a footnote.If licensed project,give project number.
3.If net peak demand for 60 minutes is not available,give that which is available specifying period.
4.If a group of employees attends more than one generating plan,report on line 11 the approximate average number of employees assignable to each
plant.
Line Item FERC Licensed Project No.1971 FERC Licensed Project No.2726
No.Plant Name:Hells Canyon Plant Name:Malad
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Storage Run-of-River
2 Plant Construction type (Conventional or Outdoor)Outdoor Outdoor
3 Year Originally Constructed 1967 1948
4 Year Last Unit was Installed 1967 1948
5 Total installed cap (Gen name plate Rating in MW)391.50 21.77
6 Net Peak Demand on Plant-Megawatts (60 minutes)436 25
7 Plant Hours Connect to Load 8,782 8,765
8 Net Plant Capability (in megawatts)O 0
9 (a)Under Most Favorable Oper Conditions 450 24
10 (b)Under the Most Adverse Oper Conditions 136 18
11 Average Number of Employees 3 2
12 Net Generation,Exclusive of Plant Use -Kwh 2,172,486,000 182,334,000
13 Cost of Plant 0 0
14 Land and Land Rights 1,563,504 205,376
15 Structures and Improvements 1,698,774 2,123,976
16 Reservoirs,Dams,and Waterways 52,511,953 3,371,066
17 Equipment Costs 14,192,053 2,690,437
18 Roads,Railroads,and Bridges 819,192 304,683
19 TOTAL cost (Total of 14 thru 18)70,785,476 8,695,538
20 Cost per KW of Installed Capacity (line 5)180.8058 399.4276
21 Production Expenses O O
22 Operation Supervision and Engineering 261,034 60,769
23 Water for Power 143,862 337,412
24 Hydraulic Expenses 162,836 34,894
25 Electric Expenses 84,737 29,733
26 Misc Hydraulic Power Generation Expenses 148,244 28,365
27 Rents 55,952 0
28 Maintenance Supervision and Engineering 65,679 14,593
29 Maintenance of Structures 33,957 21,112
30 Maintenance of Reservoirs,Dams,and Waterways 5,592 27,564
31 Maintenance of Electric Plant 153,432 17,429
32 Maintenance of Misc Hydraulic Plant 354,536 62,760
33 Total Production Expenses (total 22 thru 32)1,469,861 634,631
34 Expenses per net KWh 0.0007 0.0035
FERC FORM NO.1 (ED.12-88)Page 406.1
Name of Respondent This Report is:Date of Report Year of Report(1)g An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued)
5.The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts.Production Expenses
do not include Purchased Power,System control and Load Dispatching,and Other Expenses classified as "Other Power Supply Expenses."
6.Report as a separate plant any plant equipped with combinations of steam,hydro,internal combustion engine,or gas turbine equipment.
FERC Licensed Project No.2055 FERC Licensed Project No.503 FERC Licensed Project No.18 LinePlantName:CJ Strike Plant Name:Swan Falls I Plant Name:Twin Falls No.(d)(e)(f)
Run-of-River Run-of-River Run-of-River 1
Outdoor Conventional Conventional 2
1952 1910 1935 3
1952 1994 1995 4
82.80 25.00 52.74 5
91 22 0 6
8,760 8,775 0 7
0 0 0 8
89 26 54 9
88 11 0 10
6 4 5 11
493,024,000 123,927,000 185,489,000 12
0 0 0 13
2,052,202 51,675 279,836 14
2,666,522 25,118,690 10,804,079 15
9,739,793 13,583,476 7,908,629 16
6,764,086 29,697,810 19,508,778 17
222,132 835,9461 1,917,603 18
21,444,735 69,287,597 40,418,925 19
258.9944 2,771.5039 766.3808 20
0 0 0 21
260,004 118,184 259,953 22
88,227 31,298 28,982 23
132,139 74,100 131,103 24
14,378 17,875 11,525 25
133,656 52,770 136,082 26
56,501 6,620 926 27
59,993 110,602 22,220 28
117,531 60,917 55,070 29
49,611 9,788 31,383 30
219,901 -46,435 32,447 31
I 125,006 77,938 89,814 32
1,256,947 513,657 799,505 33
0.0025 0.0041 0.0043 34
FERC FORM NO.1 (ED.12-88)Page 407.1
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
HYDROELECTRIC GENERATING PLANT STATlŠTICS (Large Plants)
1.Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings)
2.If any plant is leased,operated under a license from the Federal Energy Regulatory Commission,or operated as a joint facility,indicate such facts in
a footnote.If licensed project,give project number.
3.If net peak demand for 60 minutes is not available,give that which is available specifying period.
4.If a group of employees attends more than one generating plan,report on line 11 the approximate average number of employees assignable to each
plant.
Line Item FERC Licensed Project No.2777 FERC Licensed Project No.2778
No.Plant Name:Upper Salmon Plant Name:Shoshone Falls
(a)(b)(c)
1 Kind of Plant (Run-of-River or Storage)Run-of-River Run-of-River
2 Plant Construction type (Conventional or Outdoor)Outdoor Conventional
3 Year Originally Constructed 1937 1907
4 Year Last Unit was Installed 1947 1921
5 Total installed cap (Gen name plate Rating in MW)34.50 12.50
6 Net Peak Demand on Plant-Megawatts (60 minutes)37 14
7 Plant Hours Connect to Load 8,783 8,729
8 Net Plant Capability (in megawatts)0 0
9 (a)Under Most Favorable Oper Conditions 39 13
10 (b)Under the Most Adverse Oper Conditions 23 6
11 Average Number of Employees 5 2
12 Net Generation,Exclusive of Plant Use -Kwh 277,924,000 111,132,000
13 Cost of Plant 0 0
14 Land and Land Rights 172,970 311,407
15 Structures and Improvements 1,403,295 1,138,033
16 Reservoirs,Dams,and Watenways 3,487,331 512,401
17 Equipment Costs 4,435,435 2,008,565
18 Roads,Railroads,and Bridges 29,359 51,383
19 TOTAL cost (Total of 14 thru 18)9,528,390 4,021,789
20 Cost per KW of Installed Capacity (line 5)276.1852 321.7431
21 Production Expenses O O
22 Operation Supervision and Engineering 152,714 60,449
23 Water for Power 72,319 20,346
24 Hydraulic Expenses 114,892 27,435
25 Electric Expenses 16,585 12,570
26 Misc Hydraulic Power Generation Expenses 131,904 50,892
27 Rents O O
28 Maintenance Supervision and Engineering 33,299 21,230
29 Maintenance of Structures 35,911 75,926
30 Maintenance of Reservoirs,Dams,and Waterways 17,425 2,491
31 Maintenance of Electric Plant 61,543 38,685
32 Maintenance of Misc Hydraulic Plant 118,498 72,006
33 Total Production Expenses (total 22 thru 32)755,090 382,030
34 Expenses per net KWh 0.0027 0.0034
FERC FORM NO.1 (ED.12-88)Page 406.2
\Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Idaho Power Company (2)A Resubmission 04/30/2001 Dec.31,2000
HYDROELECTRIC GENERATING PLANT STATISTICS (Large Plants)(Continued)
5.The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts.Production Expenses
do not include Purchased Power,System control and Load Dispatching,and Other Expenses classified as "Other Power Supply Expenses."
6.Report as a separate plant any plant equipped with combinations of steam,hydro,internal combustion engine,or gas turbine equipment.
FERC Licensed Project No.1971 FERC Licensed Project No.2061 FERC Licensed Project No.2899 LinePlantName:Common Facilities Plant Name:Lower Salmon Plant Name:Milner No.(d)(e)(f)
Run-of-River Run-of-River 1
Outdoor Conventional 2
1949 1992 3
1949 1992 4
0.00 60.00 59.45 5
0 63 71 6
0 8,781 7,041 7
0 0 0 8
0 70 59 9
0 68 0 10
0 7 2 11
0 285,301,000 170,399,000 12
0 0 0 13
80,646 403,335 138,100 14
10,077,788 839,658 10,327,402 15
13,556,785 6,458,575 17,141,809 16
819,821 6,255,019 27,290,907 17
99,051 88,693 501,877 18
24,634,091 14,045,280 55,400,095 19
0.0000 .234.0880 931.8771 20
0!0 0 21
70 642,282 194,366 22
0 41,796 1,477,004 23
2,493,048 244,746 72,967 24
0 181,633 47,406 25
0 217,754 105,128 26
0 1,076 1,282 27
0 54,338 47,214 28
0 42,365 43,965 29
0 17,653 8,931 30
0 188,703 188,314 31
78,739 100,503 51,443 32
2,571,857 1,732,849 2,238,020 33
0.0000 0.0061 0.0131 34
FERC FORM NO.1 (ED.12-88)Page 407.2
This Page Intentionally Left Blank
NameofRespondent ThisRepodis:DateofRepon YearofRepod
(1)X An Original (Mo,Da,Yr)
Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTEDATA
Schedule Page:406 Line No.:1 Column:b
American Falls generating capacity is dependent upon water
releases controlled by the United States Bureau of Reclamation.
Schedule Page:406 Line No.:1 Column:e
Cascade generating capacity is dependent upon water releases
controlled by United States Bureau Reclamation.
Schedule Page:406 Line No.:1 Column:f
Upstream storage in Brownlee Reservoir.
Schedule Page:406.1 Line No.:1 Column:b
Upstream Storage is Brownlee Reservoir.
Schedule Page:406.1 Line No.:1 Column:c
Lower Malad maximum demand 15,000 Kw Upper Malad maximum demand9,000 Kw non-coincident.
FERC FORM NO.1 (ED.12-87)Page 450
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
G ¯NERATING PLANT STATISTICS (Small Plants)
1.Small generating plants are steam plants of,less than 25,000 Kw;internal combustion and gas turbine-plants,conventional hydro plants and pumped
storage plants of less than 10,000 Kw installed capacity (name plate rating).2.Designate any plant leased from others,operated under a license from
the Federal Energy Regulatory Commission,or operated as a joint facility,and give a concise statement of the facts in a footnote.If licensed project,
give project number in footnote.
Line Year Installed Capacity Net Peak Net GenerationNameofPlantOrig.Name Plate Rating Demand Excluding Cost of Plant
No.Const.(In MW)MW Plant IJse
(a)(b)(c)(60 in.)(e)(f)
1 Hydro:
2 Clear Lakes 1937 2.50 2.0 15,333 1,033,471
3 Thousand Springs 1912 8.80 8.0 47,456 4,283,201
4
5
6 Internal Combustion:
7 Salmon Diesel (1)1967 5.00 5.0 2,792 632,410
8
9
10
11
12
13
14
15
16
17
18
19 (1)Salmon units are classified as standby.
20
21
22
23
24
25
26
!27
28
.29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
FERC FORM NO.1 (ED.12-87)Page 410
Name of Respondent This Report Is:Date of Report Year of Report(1)QX An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
GENERATING PLANT STATISTICS (Small Plants)(Continued)
3.List plants appropriately under subheadings for steam,hydro,nuclear,internal combustion and gas turbine plants.For nuclear,see instruction 11,Page 403.4.If net peak demand for 60 minutes is not available,give the which is available,specifying period.5.If any plant is equipped withcombinationsofsteam,hydro internal combustion or gas turbine equipment,report each as a separate plant.However,if the exhaust heat from the gasturbineisutilizedinasteamturbineregenerativefeedwatercycle,or for preheated combustion air in a boiler,report as one plant.
Plant Cost Per MW Operation Production Expenses Fuel Costs (in cents LinstCapacityExc'I.Fuel I-uel Maintenance Kind of Fuel (per Million Btu)(g)(h)(i)(j)(k)(I)
1
413,389 35,227 70,813 2
486,727 180,104 844,611 3
4
5
6
126,482 8,797 279,914 95,497 Diesel 7
I 8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
I
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
FERC FORM NO.1 (EE .12-87)Page 411
Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TRANSMISSION LINE STATIST CS
1.Report information concerning transmission lines,cost of firies,and expenses for year.List each transmission line having nominal voltage of 132
kilovolts or greater.Report transmission lines below these voltages in group totals only for each voltage.
2.Transmission lines include all lines covered by the definition of transmission system plant as given in the LJniform System of Accounts.Do not report
substation costs and expenses on this page.
3.Report data by individual lines for all voltages if so required by a State commission.
4.Exclude from this page any transmission lines for which plant costs are included in Account 121,Nonutility Property,
5.Indicate whether the type of supporting structure reported in column (e)is:(1)single pole wood or steel;(2)H-frame wood,or steel poles;(3)tower;
or (4)underground construction If a transmission line has more than one type of supporting structure,indicate the mileage of each type of construction
by the use of brackets and extra lines.Minor portions of a transmission line of a different type of construction need not be distinguished from the
remainder of the line.
6.Report in columns (f)and (g)the total pole miles of each transmission line.Show in column (f)the pole miles of line on structures the cost of which is
reported for the line designated;conversely,show in column (g)the pole miles of line on structures the cost of which is reported for another line.Report
pole miles of line on leased or partly owned structures in column (g).In a footnote,explain the basis of such occupancy and state whether expenses
with respect to such structures are included in the expenses reported for the line designated.
Line DEŠlÓNATION VÓLTAÒE (KV)LEN TH (Pole miles)(Indicate where Type of (the case of Number
No.Other than un rground lines
60 cycle,3 phase)Supporting report circuit miles)Of
I I Un Structure i un Structures CircuitsFromToOperatingDesignedStructureof.Line of AnotherDeslanatedLine(a)(b)(c)(d)(e)(f)(g)(h)
1 Boardman Slatt 500.0C 500.00 S Tower 1.78 1
2
3 Borah Midpoint 345.00 500.00 S Tower 85.44 1
4 Jim Bridger Goshen 345.0C 345.00 S Tower 225.88 1
5 State Line Midpoint 345.0C 345.00 S Tower 76.15 2
6 Kinport Borah 345.0C 345.00 S Tower 27.30 1
7 Midpoint Borah #1 345.0C 345.00 H Wood 79.55 1
8 Midpoint Borah #2 345.0C 345.00 H Wood 77.97 2
9 Adelaide Tap Adelaide 345.0C 345.00 H Wood 2.66 2
10
11 Quartz LaGrande 230.0C 230.00 H Wood 46.42 1
12 Midpoint Hunt 230.0C 230.00 S Tower 0.60 2
13 Brady Antelope 230.0C 230.00 H Wood 56.49 1
14 Brady Treasureton 230.0C 230.00 H Wood 0.11 1
15 Brady #1 &#2 Kinport 230.00 230.00 S Tower 18.48 2
16 Jim Bridger Point of Rocks 230.0C 230.00 H Wood 1.40 1
17 Mora Bowmont 138.0C 230.00 SP Wood 5.35 1
18.""138.0C 230.00 H Wood 10.85 1
19 Jim Bridger Point of Rocks 230.0C 230.00 H Wood 2.78 1
20 Boise Bench Caldwell 230.0C 230.00 S Tower 4.46 1
21 """230.0C 230.00 H Wood 33.75 1
22 Boise Bench Cloverdale 138.0C 230.00 S Tower 11.32 2
23 Boardman Dalreed Sub 230.0C 230.00 H Wood 1.67 1
24 Boise Bench Midpoint #1 230.0C 230.00 S Tower 0.86 i
I
25 """230.0C 230.00 H Wood 108.47 1
26 Brownlee Quartz Jct 230.0C 230.00 S Tower 1.52 1
27 """230.0C 230.00 H Wood 41.65 1
28 Brownlee Boise Bench #1 &#2 230.0C 230.00 S Tower 123.18 2
29 Oxbow Brownlee 230.0C 230.00 S Tower 10.44 2
30 Boise Bench Midpoint #2 230.0C 230.00 S Tower 3.42 1
31 """230.0C 230.00 H Wood 101.94 1
32 Oxbow Pallette Jct 230.0C 230.00 S Tower 20.14 2
33 Pallette Jct Imnaha 230.0C 230.00 H Wood 24.57 2
34
35
36 TOTAL 4,635.68 143
FERC FORM NO.1 (ED.12-87)Page 422
|Name of Respondent This Report Is:Date of Report Year of Report(1)QAn Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TRANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote if
you do not include Lower voltage lines with higher voltage lines.If two or more transmission line structures support lines of the same voltage,report the i
pole miles of the primary structure in column (f)and the pole miles of the other line(s)in column (g)
8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,
give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,for
which the respondent is not the sole owner but which the respondent operates or shares in the operation of,furnish a succinct statement explaining thearrangementandgivingparticulars(details)of such matters as percent ownership by respondent in the line,name of co-owner,basis of sharing
expenses of the Line,and how the expenses borne by the respondent are accounted for,and accounts affected.Specify whether lessor,co-owner,or
other party is an associated company.
9.Designate any transmission line leased to another company and give name of Lessee,date and terms of lease,annual rent for year,and howdetermined.Specify whether lessee is an associated company.
10.Base the plant cost figures called for in columns (j)to (1)on the book cost at end of year.
I ÖÓŠT ÓF LINE (Include in Óolumn (j)Land I'
|EXPENSES,EXCEPT DEPRECIATION AND TAXESSizeofLandrights,and clearing right-of-way)
Conductor
and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOtherCostsExpensesExpensesExpenses(i)(j)(k)(!)(m)(n)(o)(p)No.
2X1780ACSR 446,707 446,707 1
2
1272 ACSR 256,38C 21,776,998 22,033,378 3
1272 ACSR 483,30E 14,808,610 15,291,919 4
795 ACSR 571,97E 10,996,449 11,568,428 5
1272 ACSR 344,22C 6,028,033 6,372,253 6
715.5 ACSR 60,814 5,459,960 5,520,774 7
715.5 ACSR 64,851 5,620,099 5,684,950 8
715.5 ACSR 51,44E 347,946 399,394 9
10
795 ACSR 51,414 2,082,252 2,133,666 11
715.5 ACSR 9,146 395,951 405,096 12
1272 ACSR 108,301 2,282,043 2,390,344 13
795 ACSR 6,186 6,186 14
715.5 ACSR 18,82E 969,476 988,305 15
1272 ACSR 1,19C 51,525 52,715 16
715.5 ACSR 29,522 770,157 799,679 17
715.5 ACSR 18
1272 ACSR 1,89E 212,523 214,422 19
1272 ACSR 801,86E 2,720,457 3,522,323 20
715.5 ACSR 21
1272 ACSR 611,525 4,208,267 4,819,792 22
795 AAC 80,895 80,895 23
715.5 ACSR 236,147 3,357,631 3,593,778 24
715.5 ACSR 25
795 ACSR 42,996 1,660,185 1,703,180 26
795 ACSR 27
VARIOUS 635,377 9,854,377 10,489,754 28
1272 ACSR 6,032 1,030,235 1,036,268 29
715.5 ACSR 193,87E 4,351,140 4,545,016 30
VARIOUS 31
1272 ACSR 23,30E 1,884,063 1,907,371 32
1272 ACSR 138,477 1,043,217 1,181,694 33
34
35
11,042,017 208,706,135 219,748,152 4,716,008 2,466,564 1,450,839 8,633,411 36
FERC FORM NO.1 (ED.12-87)Page 423
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TRANSMISSION LINE STATISTICS
1.Report information concerning transmission lines,cost of lines,and expenses for year.List each transmission line having nominal voltage of 132
kilovolts or greater.Report transmission lines below these voltages in group totals only for each voltage.
2.Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts.Do not report
substation costs and expenses on this page.
3.Report data by individual lines for all voltages if so required by a State commission.
4.Exclude from this page any transmission lines for which plant costs are included in Account 121,Nonutility Property.
5.Indicate whether the type of supporting structure reported in column (e)is:(1)single pole wood or steel;(2)H-frame wood,or steel poles;(3)tower;
or (4)underground construction If a transmission line has more than one type of supporting structure,indicate the mileage of each type of construction
by the use of brackets and extra lines.Minor portions of a transmission line of a different type of construction need not be distinguished from the
remainder of the line.
6.Report in columns (f)and (g)the total pole miles of each transmission line.Show in column (f)the pole miles of line on structures the cost of which is
reported for the line designated;conversely,show in column (g)the pole miles of line on structures the cost of which is reported for another line.Report
pole miles of line on leased or partly owned structures in column (g).In a footnote,explain the basis of such occupancy and state whether expenses
with respect to such structures are included in the expenses reported for the line designated.
Line DE$lGNATION 'VÓLTAÓE (KV)'LE TH (Pole miles)(Indicate where Type of the case of NumberNo-other than u erground lines
60 cycle,3 ph ise)Supporting report circuit miles)Of
Un Structure Un Structures CircuitsFromToOperatingDesignedStructureofLineofAriotherDesignatedLine(a)(b)(c)(d)(e)(f)(g)(h)
1 Hells Canyon Palette Jct 230.0C 230.00 S Tower 8.27 2
2 Brown lee Boise Bench 230.0C 230.00 S Tower 102.56 2
3 Boise Bench Midpoint #3 230.0C 230.00 H Wood 106.65 1
4 Palette Jct Enterprise 230.0C 230.00 H Wood 29.62 1
5 Borah Brady #2 230.0C 230.00 S Tower 0.43 1
6 ""230.0C 230.00 H Wood 3.59 1
7 Borah Brady #1 230.0C 230.00 H Wood 3.96 1
8
9 Goshen State Line 161.0C 161.00 H Wood 90.44 1
10 Don Goshen 161.0C 161.00 S Tower 2.40 2
11 ""161.0C 161.00 H Wood 46.53 2
12
13 American Falls Power Plant Adelaide 138.0C 138.00 H Wood 84.82 2
14 ""138.0C 138.00 SPWood 2.58 2
15 Caldwell Ontario 138.0C 138.00 H Wood 27.34 1
16 ""138.0C 138.00 S Tower 3.26 1
17 Minidoka Loop "138.0C 138.00 S Tower 1.54 2
18 Nampa Caldwell 138.00 138.00 SP Wood 10.64 2
19 Upper Salmon Mountain Home Jct 138.00 H Wood 4.41 1
20 ""138.0C 138.00 H Wood 54.59 1
21 "Cliff 138.00 138.00 H Wood 30.94 1
22 Eastgate Russet 138.0C 138.00 SP Wood 2.12 1
23 Brady Fremont 138.0C 138.00 S Tower 1.00 2
24 ""138.0C 138.00 H Wood 27.98 2
25 ""138.0C 138.00 SP Wood 20.64 2
26 King Lower Malad 138.0C 138.00 H Wood 85.20 2
27 Emmett Jct Payette 138.0C 138.00 H Wood 60.87 2
28 Mountain Home AFB Tap 138.0C 138.00 H Wood 6.23 1
29 Ontario Quartz 138.00 138.00 H Wood 73.61 1
30 King American Falls PP 138.0C 138.00 S Tower 1.02 2
31 ""138.00 138.00 H Wood 135.81 1
32 ""138.0C 138.00 SP Wood 3.71 1
33
34
35 Duffin Clawson 138.0C 138.00 H Wood 6.28 1
36 TOTAL 4,635.68 143
FERC FORM NO.1 (ED.12-87)Page 422.1
Name of Respondent This Report Is:Date of Report Year of Report(1)g An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TRANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote if
you do not include Lower voltage lines with higher voltage lines.If two or more transmission line structures support lines of the same voltage,report the
pole miles of the primary structure in column (f)and the pole miles of the other line(s)in column (g)
8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,
give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,for
which the respondent is not the sole owner but which the respondent operates or shares in the operation of,furnish a succinct statement explaining thearrangementandgivingparticulars(details)of such matters as percent ownership by respondent in the line,name of co-owner,basis of sharingexpensesoftheLine,and how the expenses borne by the respondent are accounted for,and accounts affected.Specify whether lessor,co-owner,or
other party is an associated company.
9.Designate any transmission line leased to another company and give name of Lessee,date and terms of lease,annual rent for year,and howdetermined.Specify whether lessee is an associated company.
10.Base the plant cost figures called for in columns (j)to (1)on the book cost at end of year.
ÒÒST ÖF LINE (Include in Óolumn (j)Land'EXPENSES,EXCEPT DEPRECIATION AND TAXESSizeofLandrights,and clearing right-of-way)
Conductor
and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOtherCostsExpensesExpensesExpenses(i)(j)(k)(I)(m)(n)(o)(p)No.
1272 ACSR 10,737 1,214,847 1,225,584 1
954 ACSR 170,694 5,253,878 5,424,572 2
715.5 ACSR 243,29C 4,547,727 4,791,017 3
1272 ACSR 51,122 1,633,449 1,684,571 4
1272 ACSR 3,068 200,631 203,699 5
715.5 ACSR 6
1272 ACSR 10,064 180,008 190,072 7
8
250 COPPER 16,155 638,091 654,246 9
715.5 ACSR 76,041 1,511,567 1,587,608 10
397.5 ACSR 11
12
250 COPPER 26,507 2,322,486 2,348,993 13
250 COPPER 14
VARIOUS 194,762 5,386,701 5,581,464 15
1272 ACSR 16
715.5 ACSR 15,08E 249,232 264,320 17
795 AAC 157,432 1,431,576 1,589,008 18
795 ACSR 47,687 1,616,555 1,664,242 19
VARIOUS 20
795 ACSR 43,568 764,183 807,751 21
795 AAC 270,822 557,504 828,327 22
VARIOUS 548,002 3,203,239 3,751,241 23
24
25
76,822 1,282,206 1,359,029 26
52,521 1,313,280 1,365,801 27
397.5 ACSR 1,955 1,955 28
VARIOUS 34,42E 1,413,571 1,447,999 29
715.5 ACSR 134,494 3,715,850 3,850,344 30
715.5 ACSR 31
715.5 ACSR 32
33
34
4\0 4,191 309,827 314,018 35
11,042,017 208,706,135 219,748,152 4,716,008 2,466,564 1,450,839 8,633,411 36
FERC FORM NO.1 (ED.12-87)Page 423.1
Name of Respondent This R ort is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)200IdahoPowerCompanyDec.31,0
(2)A Resubmission 04/30/2001
TRANSMISSION LINE STATlST CS
1.Report information concerning transmission lines,cost of lines,and expenses for year.List each transmission line having nominal voltage of 132
kilovolts or greater.Report transmission lines below these voltages in group totals only for each voltage.
2.Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts.Do not report
substation costs and expenses on this page.
3.Report data by individual lines for all voltages if so required by a State commission.
4.Exclude from this page any transmission lines for which plant costs are included in Account 121,Nonutility Property.
5.Indicate whether the type of supporting structure reported in column (e)is:(1)single pole wood or steel;(2)H-frame wood,or steel poles;(3)tower;
or (4)underground construction If a transmission line has more than one type of supporting structure,indicate the mileage of each type of construction
by the use of brackets and extra lines.Minor portions of a transmission line of a different type of construction need not be distinguished from the
remainder of the line.
6.Report in columns (f)and (g)the total pole miles of each transmission line.Show in column (f)the pole miles of line on structures the cost of which is
reported for the line designated;conversely,show in column (g)the pole miles of line on structures the cost of which is reported for another line.Report
pole miles of line on leased or partly owned structures in column (g).In a footnote,explain the basis of such occupancy and state whether expenses
with respect to such structures are included in the expenses reported for the line designated.
Line DEŠlÓNATlÓN I VÓLTAÒE (KV)LENGTH (Pole miles)
|(Indicate where Type of (la the case of Number
No-other than underground lines
60 cycle,3 phase)Supporting report circuit miles)Of
Un Structure Un Structures Cir tFromToOperatingDesignedStructureofLineofAriothercuis
(a)(b)(c)(d)(e)Desi ated Line (h)
1 American Falls Brady Tie 138.0C 138.00 H Wood 0.38 1
2 Upper Salmon A-B King 138.0C 138.00 H Wood 6.05 1
3 Upper Salmon B Wells 138.0C 138.00 H Wood 125.70 1
4 King Wood River 138.0C 138.00 H Wood 73.98 1
5 Boise Bench Grove 138.0C 138.00 SP Wood 10.48 2
6 Quartz John Day 138.0C 138.00 H Wood 67.45 1
7 Sinker Creek Tap 138.0C 138.00 H Wood 2.80 1
8 Mora Cloverdale 138.0C 138.00 H Wood 2.57 1
9 ""138.0C 138.00 SP Wood 22.50 1
10 Fossil Gulch Tap 138.0C 138.00 H Wood 2.08 1
11 Wood River Midpoint 138.0C 138.00 H Wood 53.22 2
12 ""138.0C 138.00 SP Wood 16.74 2
13 Oxbow McCall 138.00 138.00 H Wood 38.61 1
14 ""138.00 138.00 SPWood 1.73 1
15 Lowell Jct Nampa 138.00 138.00 SP Wood 6.60 2
16 Hunt Milner 138.06 138.00 SP Wood 19.62 1
17 Strike Bruneau Bridge 138.0C 138.00 H Wood 13.51 1
18 American Falls Kramer Sub 138.0C 138.00 SP Wood 18.42 2
19 Pingree Haven 138.0C 138.00 SP Wood 11.77 1
20 Midpoint Twin Falls .138.0C 138.00 SP Wood 22.88 2
21 Twin Falls Russett 138.0C 138.00 SP Wood 1.73 1
22 Blackfoot Aiken 138.00 138.00 SPWood 6.36 2
23 Peterson Tendoy 138.0C 138.00 H Wood 57.27 1
24 Eastgate Tap Eastgate 138.0C 138.00 SPWood 7.39 1
25 Boise Bench Mora 138.0C 138.00 H Wood 13.28 2
26 Bowmont-Caldwell Simplot Sub 138.0C 138.00 SPWood 0.54 1
27 Gary Lane Eagle 138.0C 138.00 SPWood 6.54 1
28 Locust Grove Blackcat Sub 138.0C 138.00 SP Steel 7.01 1
29 Kinport Don #1 138.0C 138.00 S Tower 1.42 2
30 Twin Falls PP Tap 138.0C 138.00 H Wood 1.03 1
31 American Falls PP Amercian Falls Trans ST 138.0C 138.00 SP Steel 0.43 1
32 Lower Salmon King Tie 138.0C 138.00 H Wood 0.25 1
33 CJ Strike Strike Jct 138.0C 138.00 S Tower 4.48 2
34 Strike Jct Mountain Home Jct 138.0C 138.00 H Wood 26.62 1
35
36 TOTAL 4,635.68 143
FERC FORM NO.1 (ED.12-87)Page 422.2
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TRANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote ifyoudonotincludeLowervoltagelineswithhighervoltagelines.If two or more transmission line structures support lines of the same voltage,report thepolemilesoftheprimarystructureincolumn(f)and the pole miles of the other line(s)in column (g)8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,forwhichtherespondentisnotthesoleownerbutwhichtherespondentoperatesorsharesintheoperationof,furnish a succinct statement explaining thearrangementandgivingparticulars(details)of such matters as percent ownership by respondent in the line,name of co-owner,basis of sharingexpensesoftheLine,and how the expenses borne by the respondent are accounted for,and accounts affected.Specify whether lessor,co-owner,orotherpartyisanassociatedcompany.
9.Designate any transmission line leased to another company and give name of Lessee,date and terms of lease,annual rent for year,and howdetermined.Specify whether lessee is an associated company.
10.Base the plant cost figures called for in columns (j)to (I)on the book cost at end of year.
00$T OF LINE (Include in Column (j)Land,EXPENSES,EXCEPT DEPRECIATION AND TAXESSizeofLandrights,and clearing right-of-way)
Conductor i i iandMaterialLandConstructionandTotalCostOperation Maintenance Rents Total LineOtherCostsExpensesExpensesExpenses(i)(j)(k)(I)(m)(n)(o)(p)No.
954 ACSR 13,539 13,539 1
250 COPPER 2,741 81,732 84,473 2
VARIOUS 28,49C 1,739,407 1,767,897 3
173,682 2,169,112 2,342,795 4
225,61E 1,608,317 1,833,936 5
397.5 ACSR 92,172 1,794,136 1,886,309 6
VARIOUS 2C 77,199 77,219 7
715.5 ACSR 375,624 2,075,133 2,450,757 8
VARIOUS 9
250 COPPER 45C 67,479 67,929 10
397.5 ACSR 281,064 6,368,666 6,649,730 11
397.5 ACSR 12
397.5 ACSR 84,182 1,704,250 1,788,433 13
397.5 ACSR 14
715.5 ACSR 127,36E 920,361 1,047,730 15
715.5 ACSR 3,324 1,083,674 1,086,998 16
397.5 ACSR 14,927 586,095 601,022 17
715.5 ACSR 13,734 943,699 957,433 18
397.5 ACSR 11,212 714,859 726,072 19
VARIOUS 54,84E 1,922,807 1,977,655 20
715.5 ACSR 16,79C 207,137 223,927 21
715.5 ACSR 13,616 446,583 460,199 22
397.5 ACSR 395,696 3,442,415 3,838,111 23
715.5 ACSR 45,99C 1,057,571 1,103,561 24
715.5 ACSR 14,697 704,888 719,585 25
795 AAC 49,642 49,642 26
795 AAC 489,036 1,181,069 1,670,105 27
1272 ACSR 933,394 2,992,445 3,925,839 28
115.5 ACSR 1,174 212,777 213,951 29
250 COPPER SE 37,996 38,054 30
715.5 ACSR 76,560 76,560 31
397.5 ACSR 4,406 4,406 32
715.5 ACSR 1,074 253,872 254,946 33
397.5 ACSR 4,355 398,931 403,286 34
35
11,042,017 208,706,135 219,748,152 4,716,008 2,466,564 1,450,839 8,633,411 36
FERC FORM NO.1 (ED.12-87)Page 423.2
Name of Respondent This R ort Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
TRANSMISSION LINE STATIST CS
1.Report information concerning transmission lines,cost of lines,and expenses for year.List each transmission line having nominal voltage of 132
kilovolts or greater.Report transmission lines below these voltages in group totals only for each voltage.
2.Transmission lines include all lines covered by the definition of transmission system plant as given in the LJniform System of Accounts.Do not report
substation costs and expenses on this page.
3.Report data by individual lines for all voltages if so required by a State commission.
4.Exclude from this page any transmission lines for which plant costs are included in Account 121,Nonutility Property.
5.Indicate whether the type of supporting structure reported in column (e)is:(1)single pole wood or steel;(2)H-frame wood,or steel poles;(3)tower;
or (4)underground construction if a transmission line has more than one type of supporting structure,indicate the mileage of each type of construction
by the use of brackets and extra lines.Minor portions of a transmission line of a different type of construction need not be distinguished from the
remainder of the line.
6.Report in columns (f)and (g)the total pole miles of each transmission line.Show in column (f)the pole miles of line on structures the cost of which is
reported for the line designated;conversely,show in column (g)the pole miles of line on structures the cost of which is reported for another line.Report
pole miles of line on leased or partly owned structures in column (g).In a footnote,explain the basis of such occupancy and state whether expenses
with respect to such structures are included in the expenses reported for the line designated.
Line DESIÓNATlÓN VOLTAÓE (KV)I LENGTH (Pole miles)(Indicate where TYPB Of (In the case of Number
No.other than underground lines
60 cycle,3 phase)Supporting report circuit miles)Of
Un Structure Un Structures CircuitsFromToOperatingDesignedStructureofLineofAr)otherDesinatedLine(a)(b)(c)(d)(e)f)(g)(h)
1 Strike Jct Bowmont 138.00 H Wood 0.05 1
2 ""138.0C 138.00 S Tower 0.36 1
3 ""138.00 138.00 H Wood 68.45 1
4 Lucky Peak Lucky Peak Jct 138.0C 138.00 H Wood 4.51 2
5 Bliss King 138.00 138.00 H Wood 0.29 1
6 ""138.0C 138.00 H Wood 10.57 1
7 Milner Deadend Milner PP 138.0C 138.00 SP Wood 1.36 1
8 Swan Falls Tap 138.0C 138.00 H Wood 1.00 1
9
10
11
12 Hines BPA (Harney)115.0C 115.00 H Wood 3.41 1
13
14
15 69 Kv Lines 69.0C 69.00 H Wood 233.85 1
16 69 Kv Lines 69.0C 69.00 SP Wood 980.59 1
17
18
19 46 Kv Lines 46.0C 46.00 SP Wood 434.16 1
20
21
22
23
24
25
26
27
28 Expenses of all Lines
29
30
31
32
33
34
35
36 TOTAL 4,635.68 143
FERC FORM NO.1 (ED.12-87)Page 422.3
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
TRANSMISSION LINE STATISTICS (Continued)
7.Do not report the same transmission line structure twice.Report Lower voltage Lines and higher voltage lines as one line.Designate in a footnote if
you do not include Lower voltage lines with higher voltage lines.If two or more transmission line structures support lines of the same voltage,report the
pole miles of the primary structure in column (f)and the pole miles of the other line(s)in column (g)
8.Designate any transmission line or portion thereof for which the respondent is not the sole owner.If such property is leased from another company,
give name of lessor,date and terms of Lease,and amount of rent for year.For any transmission line other than a leased line,or portion thereof,for
which the respondent is not the sole owner but which the respondent operates or shares in the operation of,furnish a succinct statement explaining thearrangementandgivingparticulars(details)of such matters as percent ownership by respondent in the line,name of co-owner,basis of sharing
expenses of the Line,and how the expenses borne by the respondent are accounted for,and accounts affected.Specify whether lessor,co-owner,or
other party is an associated company.
9.Designate any transmission line leased to another company and give name of Lessee,date and terms of lease,annual rent for year,and how
determined.Specify whether lessee is an associated company.
10.Base the plant cost figures called for in columns (j)to (I)on the book cost at end of year.
I CÓ$T ÓF LINE (Include in Column (j)Land'EXPENSES,EXCEPT DEPRECIATION AND TAXESSizeofLandrights,and clearing right-of-way)
Conductor i i
and Material Land Construction and Total Cost Operation Maintenance Rents Total LineOtherCostsExpenses|Expenses Expenses(i)(j)(k)(I)(m)(n)(o)(p)No.
715.5 ACSR 22,141 1,481,009 1,503,150 1
715.5 ACSR 2
3
715.5 ACSR 4
VARIOUS 7 114,235 114,242 5
115.5 ACSR 5,62C 445,666 451,286 6
715.5 ACSR 2,814 183,606 186,420 7
397.5 ACSR 12,885 261,511 274,396 8
397.5 ACSR 9
10
11
397.5 ACSR 1,976 63,404 65,382 12
13
14
VARIOUS 482,607 23,276,057 23,758,664 15
16
17
18
VARIOUS 176,265 6,752,100 6,928,365 19
20
21
22
23
24
25
26
27
4,716,008 2,466,564 1,450,839 8,633,411 28
29
30
31
32
33
34
35
11,042,017 208,706,135 219,748,152 4,716,008 2,466,564 1,450,839 8,633,411 36
FERC FORM NO.1 (ED.12-87)Page 423.3
Name of Respondent This Report is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
RANSMISSION LINES ADDED DURING YEAR
1.Report below the information called for concerning Transmission lines added or altered during the year.It is not necessary to report
minor revisions of lines.
2.Provide separate subheadings for overhead and under-ground construction and show each transmission line separately.If actual
costs of competed construction are not readily available for reporting columns (I)to (o),it is permissible to report in these columns the
Line LINE DESlÓNATION Line SUPPÓRTING STRUÖTURE ÔlRÓUITS PER STRUÓTURLengthAverageNo.From To in Type Number per Present UltimateMilesMiles
(a)(b)(c)(d)(e)(f)(g)
1 No new lines added for 2000.
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44 TOTAL
FERC FORM NO.1 (ED.12-86)Page 424
Name of Respondent This R ort is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000idahoPowerCompanyDec.31,(2)A Resubmission 04/30/2001
TRANSMISSION LINES ADDED DURING YEAR (Continued)
costs.Designate,however,if estimated amounts are reported.Include costs of Clearing Land and Rights-of-Way,and Roads and
Trails,in column (I)with appropriate footnote,and costs of Underground Conduit in column (m).
3.If design voltage differs from operating voltage,indicate such fact by footnote;also where line is other than 60 cycle,3 phase,
indicate such other characteristic.
CONDUCTORŠ Voltage LINE ÓOST 'LineSizeSpecificationConfigurationKVLandandPoles,Towers Conductors Total No.and Spacing (Operating)Land Rights and Fixtures and Devices(h)(i)(j)(k)(1)(m)(n)(o)
1
2
3
4
5
6
7
8
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
FERC FORM NO.1 (ED.12-86)Page 425
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line VOLTAGE (In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 Adelaide transmission 345.00 138.00 13.80
2 Aiken distribution 69.00 46.00 13.80
3 Alameda "46.00 12.50
4 ""138.00 12.50
5 American Falls PP -attended transmission 138.00 13.80
6 American Falls "138.00 46.00 13.80
7 Artesian distribution 69.00 46.00 13.80
8 Bannock Creek "46.00 12.50
9 Bethel Court "69.00 13.00
10 Black Cat "138.00 13.09
11 Blackfoot "46.00 12.50
12 ""138.00 38.00 13.80
13 Bliss -attended transmission 138.00 13.80
14 Blue Gulch distribution 138.00 34.50
15 Boise Bench -attended transmission 138.00 34.50 13.80
16 ""138.00 69.00 13.80
17 ""230.00 138.00 13.80
18 Boise Cascade Emmett CSPP distribution 69.00 12.50
19 Boise Cascade 1
"69.00 12.50
20 Boise "138.00 12.50
21 Borah transmission 161.00 138.00 13.80
22 Bowmont distribution 38.00 7.20
23 ""138.00 34.50
24 ""138.00 69.00 13.80
25 Brady transmission 46.00 12.50
26 ""138.00 69.00 12.50
27 ""230.00 138.00 13.80
28 Brownlee -attended transmission 230.00 13.80
29 Bruneau Bridge distribution 138.00 34.50
30 Buckhorn "69.00 38.00
31 Buhl "46.00 12.50
32 Burley Rural "69.00 12.50
33 Butler "138.00 12.50
34 Caldwell "138.00 12.50
35 ""138.00 69.00 13.80
36 ""230.00 138.00 12.50
37 Canyon Creek "138.00 34.50
38 ""138.00 69.00 13.80
39 Cascade Power Plant -attended Transmission 69.00 4.20
40 Chestnut distribution 138.00 12.50
FERC FORM NO.1 (ED.12-96)Page 426
Name of Respondent This Report Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)200IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,0
SUBSTATIONS (Continued)
5.Show in columns (1),(j),and (k)special equipment such as rotary converters,rectifiers,condensers,etc.and auxiliary equipment forincreasingcapacity.
6.Designate substations or major items of equipment leased from others,jointly owned with others,or operated otherwise than byreasonofsoleownershipbytherespondent.For any substation or equipment operated under lease,give name of lessor,date andperiodoflease,and annual rent.For any substation or equipment operated other than by reason of sole ownership or lease,give nameofco-owner or other party,explain basis of sharing expenses or other accounting between the parties,and state amounts and accountsaffectedinrespondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUlPMENT LineTransformersSpare(in Service)(In MVa)in Serviœ Transformers Type of Equipment Number of Units Total Capacity No.
(In MVa)(f)(9)(h)(i)(j)(k)
300 2 1
10 1 2
15 1 3
18 1 4
72 1 5
25 1 6
10 1 7
10 1 8
12 1 9
28 1 10
30 2 11
67 3 1 12
69 3 13
15 1 14
56 3 15
100 4 16
354 3 1 17
12 1 18
10 1 19
49 2 20
450 3 1 21
8 3 22
18 1 23
25 1 24
3 25
1 26
300 3 27
734 5 1 28
33 2 29
20 1 30
20 2 31
12 1 32
33 2 33
33 2 34
40 2 35
120 1 36
15 1 37
8 1 38
12 1 39
34 2 40
FERC FORM NO.1 (ED.12-96)Page 427
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line VOLTAGE (in MVa)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 Clear Lake -attended transmission 46.00 2.30
2 Cliff "69.00 38.00 12.50
3 Cloverdale Transmission 138.00 12.50
4 ""138.00 69.00 12.50
5 Dale "46.00 12.50
6 ""69.00 12.50
7 ""138.00 34.50
8 ""138.00 13.80
9 Don "138.00 7.20
10 ""138.00 7.60
11 ""138.00 13.80 7.20
12 "'138.00 13.80
13 ""161.00 138.00 12.50
14 DRAM "138.00 13.00
15 ""230.00 138.00 13.80
16 Duffin "138.00 34.50
17 Eagle "138.00 12.50
18 Eastgate '138.00 12.50
19 Eden "138.00 34.50
20 ""138.00 46.00 12.50
21 Elmore "138.00 34.50
22 ""138.00 69.00 12.50
23 Emmett distribution 138.00 12.50
24 ""138.00 69.00 12.50
25 Falls "46.00 12.50
26 Filer "46.00 12.50
27 Flying H "69.00 13.80
28 Fort Hall "46.00 12.50
29 Fossil Gulch "138.00 13.80 4.60
30 ""138.00 34.50
31 Fremont transmission 69.00 38.00 12.50
32 Gary distribution 138.00 13.00
33 Gem distribution 69.00 12.50
34 Golden Valley "69.00 12.50
35 Gowen Substation "138.00 36.00
36 Grindstone "35.00 12.50
37 Grove "138.00 12.50
38 Hagerman "46.00 12.50
39 Hailey "138.00 12.50
40 Haven "46.00 34.50
FERC FORM NO.1 (ED.12-96)Page 426.1
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS (Continued)
5.Show in columns (l),(j),and (k)special equipment such as rotary converters,rectifiers,condensers,etc.and auxiliary equipment forincreasingcapacity.
6.Designate substations or major items of equipment leased from others,jointly owned with others,or operated otherwise than byreasonofsoleownershipbytherespondent.For any substation or equipment operated under lease,give name of lessor,date andperiodoflease,and annual rent.For any substation or equipment operated other than by reason of sole ownership or lease,give nameofco-owner or other party,explain basis of sharing expenses or other accounting between the parties,and state amounts and accountsaffectedinrespondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUlPMENT LineTransformersSpare
!(In Service)(in MVa)In Service Transformers Type of Equipment Number of Units Total Capacity No.
(In MVa)(f)(g)(h)(i)(j)(k)
4 1 1
25 3 1 2
15 1 3
50 2 4
2 5
2 6
40 1 1 7
25 1 8
226 15 9
54 3 10
15 1 11
26 1 12
80 1 13
67 4 14
160 2 15
36 2 16
33 2 17
36 2 18
58 2 19
15 1 20
16 1 21
30 2 22
15 1 23
25 1 24
15 2 25
10 1 26
10 1 27
14 2 28
8 1 29
15 1 30
50 3 1 31
20 1 32
10 1 33
14 2 34
30 1 35
10 2 36
35 2 37
12 2 38
20 1 39
12 1 40
FERC FORM NO.1 (ED.12-96)Page 427.1
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line VOLTAGE (In MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 Hewlett Packard "138.00 13.10
2 Hidden Springs "138.00 13.09
3 Highland "138.00 13.09
4 Hill "138.00 12.50
5 Homedale "69.00 12.50
6 Horseshoe Bend Distribution 35.00 12.50
7 ""69.00 12.50
8 ""69.00 25.00
9 Hunt transmission 230.00 138.00 13.80
10 Hydra distribution 138.00 34.50
11 Island "69.00 12.50
12 Jerome "46.00 12.50
13 ""69.00 12.50
14 Julion Clawson "138.00 34.50
15 """69.00 13.80
16 Karcher "138.00 13.09
17 Kenyon "69.00 12.50
18 Ketchum "138.00 12.50
19 Kinport transmission 69.00 38.00 12.50
20 ""230.00 138.00 12.50
21 ""230.00 138.00 13.80
22 ""161.00 138.00 13.80
23 Kramer distribution 138.00 34.50
24 Lansing "69.00 2.50
25 Linden "138.00 69.00 13.80
26 Locust "138.00 34.50
27 Lower Malad -attended transmission 138.00 6.60
28 Lower Salmon -attended "138.00 13.80
29 Map Rock distribution 69.00 12.50
30 McCall "35.00 25.00
31 ""69.00 12.50
32 ""138.00 35.00
33 ""138.00 69.00 12.50
34 Meridian "69.00 12.50
35 Micron "138.00 12.50
36 Midpoint transmission 230.00 138.00 12.50
37 ""345.00 230.00 13.80
38 ""500.00 345.00
39 Milner distribution 69.00 38.00 13.80
40 ""69.00 38.00 7.20
FERC FORM NO.1 (ED.12-96)Page 426.2
Name of Respondent This Re ort is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS (Continued)
5.Show in columns (1),(j),and (k)special equipment such as rotary converters,rectifiers,condensers,etc.and auxiliary equipment forincreasingcapacity.
6.Designate substations or major items of equipment leased from others,jointly owned with others,or operated othenvise than byreasonofsoleownershipbytherespondent.For any substation or equipment operated under lease,give name of lessor,date andperiodoflease,and annual rent.For any substation or equipment operated other than by reason of sole ownership or lease,give nameofco-owner or other party,explain basis of sharing expenses or other accounting between the parties,and state amounts and accountsaffectedinrespondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUlPMENT LineTransformersSpare(in Service)(In MVa)In Service Transformers Type of Equipment Number of Units Total Capacity No.(in MVa)(f)(9)(h)(i)(j)(k)
20 1 1
8 1 2
12 1 3
15 1 4
15 2 5
6 1 6
10 1 7
5 1 8
300 3 9
18 1 10
12 1 11
10 1 12
10 1 13
30 2 14
20 3 15
12 1 16
20 2 17
58 2 18
3 19
I180 1 1 20
I180 1 21
600 3 1 22
30 2 23
10 1 24
18 1 25
42 2 26
15 1 27
70 4 28
10 1 29
3 3 30
8 1 31
18 1 32
30 1 33
24 2 34
48 4 35
120 1 36
600 2 37
1000 4 38
125 3 1 39
8 3 1 40
FERC FORM NO.1 (ED.12-96)Page 427.2
Name of Respondent This Report Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line VOLTAGE (In MVa)
No.Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1
""138.00 34.50
2 Milner PP -attended transmission 138.00 13.80
3 Moonstone distribution 138.00 34.50
4 Mora "138.00 34.50
5 Moreland "46.00 12.50
6 ""46.00 34.50
7 Mountain Home Distribution 69.00 12.50
8 Mountain Home Air Force Base "69.00 12.50
9 ""138.00 12.50
10 Nampa "69.00 12.50
11 ""138.00 12.50
12 ""138.00 69.00 12.50
13 New Plymouth "69.00 12.50
14 Parma "69.00 12.50
15 ""69.00 34.50
16 Paul '138.00 34.50 12.50
17 Payette "138.00 12.50
18 Pingree "138.00 12.50
19 ""138.00 36.00
20 Pleasant Valley "138.00 34.50
21 Pocatello "46.00 12.50
22 Portneuf "138.00 36.20
23 Rockford "46.00 12.50
24 Russett "138.00 12.50
25 Sailor Creek "138.00 13.80 4.60
26 ""138.00 34.50
27 Salmon "69.00 12.50
28 ""69.00 7.50
29 Shoshone Falls -attached transmission 46.00 2.30
30 ""46.00 6.60
31 Silver distribution 138.00 34.50
32 Simplot distribution 138.00 12.50
33 Sinker Creek "138.00 34.50
34 Siphon "138.00 34.50
35 South Park "69.00 12.50
36 State "69.00 12.50
37 Strike Power Plant -attended transmission 138.00 13.80
38 Sugar distribution 138.00 34.50
39 Swan Falls -attended Transmission 138.00
40 Taber distribution 46.00 12.50
FERC FORM NO.1 (ED.12-96)Page 426.3
Name of Respondent This Report Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000idahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS (Continued)
5.Show in columns (l),(j),and (k)special equipment such as rotary converters,rectifiers,condensers,etc.and auxiliary equipment forincreasingcapacity.
6.Designate substations or major items of equipment leased from others,jointly owned with others,or operated otherwise than byreasonofsoleownershipbytherespondent.For any substation or equipment operated under lease,give name of lessor,date and
period of lease,and annual rent.For any substation or equipment operated other than by reason of sole ownership or lease,give name
of co-owner or other party,explain basis of sharing expenses or other accounting between the parties,and state amounts and accountsaffectedinrespondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Number of Numberof CONVERSION APPARATUS AND SPECIAL EQUIPMENT Line
(In Service)(in MVa)Transfeoreers TranSsoar
ers Type of Equipment Number of Units Tot CMapaacityNo.
(f)(g)(h)(i)(j)(k)
29 2 1
36 1 2
12 1 3
33 2 4
8 1 5
10 3 1 6
10 1 7
10 1 8
18 1 9
15 1 10
55 2 11
25 1 12
10 1 13
10 1 14
12 1 15
30 2 16
15 2 17
20 1 18
20 1 19
42 2 20
36 2 21
18 1 22
14 2 23
18 1 24
8 2 25
15 1 26
6 3 1 27
8 3 1 28
3 1 29
10 1 30
12 1 31
15 1 32
12 1 33
33 2 34
10 1 35
33 2 36
83 3 37
10 1 38
30 1 39
5 1 40
FERC FORM NO.1 (ED.12-96)Page 427.3
Name of Respondent This Re ort Is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line VOLTAGE (in MVa)
No Name and Location of Substation Character of Substation Primary Secondary I Tertiary
(a)(b)(c)(d)(e)
1
""46.00 34.50
2 Terry "138.00 12.50
3 Thousand Springs -attended transmission 46.00 6.90
4 ""69.00 46.00 2.30
5 Toponis distribution 138.00 34.50
6 Twin Falls "46.00 7.20
7 Twin Falls distribution 46.00 12.50
8 ""69.00 12.50
9 ""138.00 13.00
10 ""138.00 46.00 12.50
11 Twin Falls PP -attended transmission 138.00 7.20
12 ""138.00 13.20
13 Upper Malad -attended "46.00 7.20
14 Upper Salmon-attended "138.00 7.20
15 Ustick distribution 138.00 12.50
16 Victory "138.00 12.50
17 Ware "69.00 12.50
18 Weiser "69.00 12.50
19 ""138.00 69.00 12.50
20 Wye distribution 69.00 12.50
21 Zilog "69.00 12.50
22
23
24 The above are all State of Idaho
25
26 Montana:
27 Peterson transmission 138.00 38.00 12.50
28
29 Nevada:
30 Valmy -attended transmission 345.00 21.30
31 Wells "138.00 69.00 12.50
32
33 Oregon:
34 Boardman -attended transmission 500.00 24.00
35 Cairo distribution 69.00 12.50
36 Hells Canyon -attended transmission 230.00 13.80
37 Hines "138.00 115.00 12.50
38 Malheur Butte distribution 69.00 34.50 12.50
39 Nyssa "69.00 12.50
40 Ontario "138.00 12.50
FERC FORM NO.1 (ED.12-96)Page 426.4
Name of Respondent This Re ort Is:Date of Report Year of Report(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS (Continued)
5.Show in columns (l),(j),and (k)special equipment such as rotary converters,rectifiers,condensers,etc.and auxiliary equipment forincreasingcapacity.
6.Designate substations or major items of equipment leased from others,jointly owned with others,or operated otherwise than byreasonofsoleownershipbytherespondent.For any substation or equipment operated under lease,give name of lessor,date andperiodoflease,and annual rent.For any substation or equipment operated other than by reason of sole ownership or lease,give nameofco-owner or other party,explain basis of sharing expenses or other accounting between the parties,and state amounts and accountsaffectedinrespondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation Number of Number of CONVERSION APPARATUS AND SPECIAL EQUIPMENT LineTransformersSpare(In Service)(In MVa)In Service Transformers Type of Equipment Number of Units Total Capacity No.
(In MVa)(f)(g)(h)(i)Q)(k)
3 3 1 1
42 3 2
8 1 3
5 3 1 4
18 1 5
1 6
1 7
1 8
67 2 9
13 1 10
9 1 11
72 1 12
8 1 13
36 4 14
44 2 15
24 1 16
10 1 17
17 2 18
25 1 19
47 3 20
25 2 21
22
23
24
25
26
I2431 27
28
29
150 1 30
18 3 1 31
32
33
55 1 34
12 1 35
500 3 1 36
40 1 37
10 3 38
20 2 39
38 2 40
FERC FORM NO.1 (ED.12-96)Page 427.4
Name of Respondent This Report is:Date of Report Year of Report
(1)X An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS
1.Report below the information called for concerning substations of the respondent as of the end of the year.
2.Substations which serve only one industrial or street railway customer should not be listed below.
3.Substations with capacities of Less than 10 MVa except those serving customers with energy for resale,may be grouped according
to functional character,but the number of such substations must be shown.
4.Indicate in column (b)the functional character of each substation,designating whether transmission or distribution and whether
attended or unattended.At the end of the page,summarize according to function the capacities reported for the individual stations in
column (f).
Line VOLTAGE (in MVa)
No Name and Location of Substation Character of Substation Primary Secondary Tertiary
(a)(b)(c)(d)(e)
1 ""138.00 69.00 12.50
2 ""230.00 138.00 12.50
3 Ore-Ida "69.00 12.50
4 Oxbow -attended transmission 69.00 38.00 12.50
5 ""230.00 13.80
6 Oxbow Attended transmission 230.00 138.00 13.80
7 Quartz transmission 138.00 69.00 12.50
8 ""138.00 80.00 12.50
9 Vale distribution 69.00 13.09
10
11 Wyoming:
12 Jim Bridger -attended transmission 345.00 22.00
13
14
15
16
17
18
19 Transformers-distribution substations under 10,000
20 KVA 85 unattended.
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
FERC FORM NO.1 (ED.12-96)Page 426.5
Name of Respondent This Report is:Date of Report Year of Report(1)DX An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
SUBSTATIONS (Continued)
5.Show in columns (l),(j),and (k)special equipment such as rotary converters,rectifiers,condensers,etc.and auxiliary equipment for
increasing capacity.
6.Designate substations or major items of equipment leased from others,jointly owned with others,or operated otherwise than byreasonofsoleownershipbytherespondent.For any substation or equipment operated under lease,give name of lessor,date andperiodoflease,and annual rent.For any substation or equipment operated other than by reason of sole ownership or lease,give name
of co-owner or other party,explain basis of sharing expenses or other accounting between the parties,and state amounts and accountsaffectedinrespondent's books of account.Specify in each case whether lessor,co-owner,or other party is an associated company.
Capacity of Substation |Number of I Number of CONVERSION APPARATUS AND SPECIAL EQUlPMENT ILine
(In Service)(in MVa)Transfeorreers TranSsoarrreers Type of Equipment Number of Units Total CMapaacityNo.
(f)(9)(h)(i)(j)(k)
55 3 1
120 1 2
12 1 3
10 3 1 4
244 2 5
100 1 6
63 3 7
100 3 8
8 1 9
10
11
748 1 12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
FERC FORM NO.1 (ED.12-96)Page 427.5
Name of Respondent This Report Is:Date of Report Year of Report
(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ELECTR C DISTRIBUTION METERS AND LINE TRANSFORMERS
1.Report below the information called for concerning distribution watt-hour meters and line transformers.
2.Include watt-hour demand distribution meters,but not external demand meters.
3.Show in a footnote the number of distribution watt-hour meters or line transformers held by the respondent under lease from others,
jointly owned with others,or held otherwise than by reason of sole ownership by the respondent.If 500 or more meters or line
transformers are held under a lease,give name of lessor,date and period of lease,and annual rent.If 500 or more meters or line
transformers are held other than by reason of sole ownership or lease,give name of co-owner or other party,explain basis of
accounting for expenses between the parties,and state amounts and accounts affected in respondent's books of account.Specify in
each case whether lessor,co-owner,or other party is an associated company.
Line Item Number of Watt-hour LINE TRANSFORMERS
No.Meters Number Total capacity (in (MVa)
(a)(b)(c)(d)
1 Number at Beginning of Year 395,646 191,916 9,233
2 Additions During Year
3 Purchases 18,145 5,616 410
4 Associated with Utility Plant Acquired
5 TOTAL Additions (Enter Total of lines 3 and 4)18,145 5,616 410
6 Reductions During Year
7 Retirements 7,386 1,434 57
8 Associated with Utility Plant Sold
9 TOTAL Reductions (Enter Total of lines 7 and 8)7,386 1,434 57
10 Number at End of Year (Lines 1 +5 -9)406,405 196,098 9,586
11 in Stock 5,398 189,588 9,121
12 Locked Meters on Customers'Premises
13 Inactive Transformers on System
14 In Customers'Use 400,927 4,596 451
15 In Company's Use 80 1,914 14
16 TOTAL End of Year (Total 11 to 15.This should equal line 10)406,405 196,098 9,586
FERC FORM NO.1 (ED.12-88)Page 429
Name of Respondent This Report Is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)Dec.31 2000IdahoPowerCompany(2)A Resubmission 04/30/2001 '
ENVIRONMENTAL PROTECTION FACl]TIES
1.For purposes of this response,environmental protection facilities shall be defined as any building,structure,equipment,facility,orimprovementdesignedandconstructedsolelyforcontrol,reduction,prevention or abatement of discharges or releases into theenvironmentofgaseous,Liquid,or solid substances,heat,noise or forthe control,reduction,prevention,or abatement of any otheradverseimpactofanactivityontheenvironment.
2.Report the differences in cost of facilities installed for environmental considerations over the cost of alternative facilities which wouldotherwisebeusedwithoutenvironmentalconsiderations.Use the best engineering design achievable without environmentalrestrictionsasthebasisfordetermirlingcostswithoutenvironmentalconsiderations.It is not intended that special design studies bemadeforpurposesofthisresponse.Base the response on the best engineering judgment where direct comparisons are not available.Include in these differences in costs the costs or estimated costs of environmental protection facilities in service,constructed ormodifiedinconnectionwiththeproduction,transmission,and distribution of electrical energy and shall be reported herein for all suchenvironmentalfacilitiesplacedinserviceonorafterJanuary1,1969,so long as it is readily determinable that such facilities wereconstructedormodifiedforenvironmentalratherthanoperationalpurposes.Also report similar expenditures for environmental plantincludedinconstructionworkinprogress.Estimate the cost of facilities when the original cost is not available or facilities are jointlyownedwithanotherutility,provided the respondent explains the basis of such estimations.Examples of these costs would include aportionofthecostsoftallsmokestacks,underground Lines,and landscaped substations.Explain such costs in a footnote.
3.In the cost of facilities reported on this page,include an estimated portion of the cost of plant that is or will be used to provide power
to operate associated environmental protection facilities.These costs may be estimations on a percentage of plant basis.Explain suchestimationsinafootnote.
4.Report all costs under the major classifications provided below and include,as a minimum,the items Listed-hereunder:A.Air pollution control facilities:D.Noise abatement equipment:
(1)Scrubbers,precipitators,tall smokestacks,etc.(1)Structures
(2)Changes necessary to accommodate use of (2)mufflersenvironmentallycleanfuelssuchasLowashorlow(3)Sound proofing equipmentsulfurfuelsincludingstorageandhandlingequipment(4)Monitoring equipment
(3)Monitoring equipment (5)Other.
(4)Other.E.Esthetic costs:
B.Water pollution control facilities:(1)Architectural costs
(1)Cooling towers,ponds,piping,pumps,etc.(2)Towers
(2)Waste water treatment equipment (3)Underground lines
(3)Sanitary waste disposal equipment (4)Landscaping
(4)Oil interceptors (5)Other.
(5)Sediment control facilities F.Additional plant capacity necessary due to
(6)Monitoring equipment restricted output from existing facilities,or addition(7)Other.of pollution control facilities.
C.Solid waste disposal costs:G.Miscellaneous:
(1)Ash handling and disposal equipment (1)Preparation of environmental reports
(2)Land (2)Fish and wildlife plants included in Accounts
(3)Settling ponds 330,331,332,and 335.
(4)Other.(3)Parks and related facilities
(4)Other.
5.In those instances when costs are composites of both actual supportable costs and estimates of costs,specify in column (f)theactualcoststhatareincludedincolumn(e).
6.Report construction work in progress relating to environmental facilities at Line 9.
I
Line Classification of Cost C BANGES DURING YEAR Balance at Actual CostNoAdditionsRetirementsAdjustmentsEndofYear
(a)(b)(c)(d)(e)(f)
1 Air Pollution Control Facilities 760,546 18,887 147,646,642 147,646,642
2 Water Pollution Control Facilities 68,091 17,891,598 17,891,598
3 Solid Waste Disposal Costs 28,941 3,637,521 3,637,521
4 Noise Abatement Equipment 168,063 168,063
5 Esthetic Costs 5,140 1,047,634 1,047,634
6 Additional Plant Capacity 78,161 32,183 6,859,100 6,859,100
7 Miscellaneous (Identify significant)65,186 26,775,892 22,194,285
8 TOTAL (Total of lines 1 thru 7)1,006,065 51,070 204,026,450 199,444,843
9 Construction Work in Progress 4,408,137 4,408,137
FERC FORM NO.1 (ED.12-88)Page 430
'Name of Respondent This Report is:Date of Report Year of Report(1)An Original (Mo,Da,Yr)2000IdahoPowerCompany(2)A Resubmission 04/30/2001 Dec.31,
ENVIRONMENTAL PROTECTION EXPENSES
1.Show below expenses incurred in connection with the use of environmental protection facilities,the cost of which are reported on
Page 430.Where it is necessary that allocations and/or estimates of costs be made,state the basis or method used.
2.Include below the costs incurred due to the operation of environmental protection equipment,facilities,and programs.
3.Report expenses under the subheadings listed below.
.4.Under ltem 6 report the difference in cost between environmentally clean fuels and the alternative fuels that would otherwise be
used and are available for use.
5.Under ltem 7 include the cost of replacement power,purchased or generated,to compensate for the deficiency in output from
existing plants due to the addition of pollution control equipment,use of alternate environmentally preferable fuels or environmental
regulations of governmental bodies.Base the price of replacement power purchased on the average system price of purchased power
if the actual cost of such replacement power is not known.Price internally generated replacement power at the system average cost of
power generated if the actual cost of specific replacement generation is not known.
6.Under item 8 include ad valorem and other taxes assessed directly on or directly relatable to environmental facilities.Also include
under Item 8 licensing and similar fees on such facilities.
7.In those instances where expenses are composed of both actual supportable data and estimates of costs,specify in column (c)the
actual expenses that are included in column (b).
Line Ólassification of Expenses Amount Actual Expenses
No.(a)(b)(c)
1 Depreciation 5,938,473
2 Labor,Maint,Mtris,&Supplies Cost Related to Env Fac &Programs 14,429,440 14,390,523
3 Fuel Related Costs
4 Operation of Facilities 2,272,035 2,272,035
5 Fly Ash and Sulfur Sludge Removal 488,396 488,396
6 Difference in Cost of Environmentally Clean Fuels
7 Replacement Power Costs 2,870,582 499,121
8 Taxes and Fees 731,718
9 Administrative and General 342,461 342,461
10 Other (Identify significant)17,299 17,299
11 TOTAL 27,090,404 18,009,835
FERC FORM NO.1 (ED.12-88)Page 431
NameofRespondent ThisRepodis:DateofRepod YearofReport
(1)X An Original (Mo,Da,Yr)Idaho Power Company (2)_A Resubmission 04/30/2001 Dec 31,2000
FOOTNOTEDATA
Schedule Page:431 Line No.:1 Column:bAppropriaterateswereappliedtoestimated plant investment in environmental facilitiesatbeginningofyear.
Schedule Page:431 Line No.:2 Column:b
All of the Jim Bridger environmental expenses were provided by Pacific Power.All theBoardmanenvironmentalexpenseswereprovidedbyPortlandGeneralElectric.All of theValmyenvironmentalexpenseswereprovidedbySierraPacificPower.Other environmentalexpensesareacombinationofengineeringestimates,allocations based on relative plantinvestmentandcertainO&M accounts directly identifiable as environmental.
Schedule Page:431 Line No.:7 Column:b
For the Boardman,Valmy and Jim Bridger plants,estimated energy costs were provided byPortlandGeneral,Sierra Pacific and Pacific Power.
Schedule Page:431 Line No.:8 Column:b
Property taxes were allocated on the basis of relative investment in environmentalfacilities.
FERC FORM NO.1 (ED.12-87)Page 450
INDEX
Schedule Page No.
Accrued and prepaid taxes ......................262-263
Accumulated Deferred Income Taxes ....................234
272-277
Accumulated provisions for depreciation of
common utility plant ....................356
utility plant ......................219
utility plant (summary).....................200-201
Advances
from associated companies .....................256-257
Allowances ..........
...........228-229
Amortization
miscellaneous ....................340
of nuclear fuel ..........................202-203
Appropriations of Retained Earnings ....................118-119
Associated Companies
advances from ...............................256-257
corporations controlled by respondent .....................103
control over respondent ..,..................102
interest on debt to ......................256-257
Attestation ....................i
Balance sheet
comparative ....................110-113
notes to .....................122-123
Bonds ......................256-257
Capital Stock .....................251
discount ....................254
expense .......................254
installments recived .....................252
premiums ......................252
reacquired .....................251
subscribed .....................252
Cash flows,statement of .....................120-121
Changes
important during year .....................108-109
Construction
overheads,electric ................................217
overhead procedures,general description of ....................218
work in progress -common utility plant ....................356
work in progress -electric ...........................216
work in progress -other utility departments .....................200-201
Control
corporations controlled by respondent ....................103
over respondent ..........................102
security holders and voting powers ......................106-107
Corporation
controlled by .....................103
incorporated ........................101
CPA,background information on ......................101
CPA Certification,this report form ......................i-ii
FERC FORM NO.1 (ED.12-93)Index 1
INDEX (continued)
Schedule PaqeNo.Deferred
credits,other .......................269debits,miscellaneous ...........................233incometaxesaccumulated-accelerated
amortization property .............................272-273incometaxesaccumulated-other property ....................274-275incometaxesaccumulated-other ................................276-277incometaxesaccumulated-pollution control facilities .....................234Definitions,this report form .......................iiiDepreciationandamortization
of common utility plant ....................356ofelectricplant.....................219
336-337Directors...........................105Discountoncapitalstock......................254Discount-premium on long-term debt .....................256-257Distributionofsalariesandwages.....................354-355Dividendappropriations......................118-119Earnings,Retained .....................118-119
Electric energy account .......................401Environmentalprotection
expenses ..........
..........431
facilities ........................430Expenses
electric operation and maintenance ....................320-323
electric operation and maintenance,summary .....................323
unamortized debt .....................256Extraordinarypropertylosses......................230Filingrequirements,this report form
General description of construction overhead procedure .....................218
General information ...........................101
Instructions for filing the FERC Form 1 ......................i-ivGeneratingplantstatistics
hydroelectric (large).....................406-407
pumped storage (large)......................408-409
small plants .....................410-411
steam-electric (large)..........................402-403Hydro-electric generating plant statistics ....................406-407Identification.........................101Importantchangesduringyear......................108-109
Income
statement of,by departments ............................114-117statementof,for the year (see also revenues).....................114-117deductions,interest on debt to associated companies .....................340deductions,miscellaneous amortization .......................340deductions,other income deduction ......................340deductions,other interest charges .....................340Incorporationinformation.......................101
Installments received on capital stock .....................252
FERC FORM NO.1 (ED.12-95)Index 2
INDE]<(continued)
Schedule Pace No.
Interest
charges,on debt to associated companies .....................340
charges,other .....................................340
charges,paid on long-term debt,advances,etc ....................256-257
Investments
nonutility property .....................221
subsidiary companies ............................224-225
Investment tax credits,accumulated deferred .....................266-267
Law,excerpts applicable to this report form ....................iv
List of schedules,this report form .....................2-4
Long-term debt ........................256-257
Losses-Extraordinary property .....................230
Materials and supplies ....................227
Meters and line transformers .....................429
Miscellaneous general expenses ...................335
Notes
to balance sheet .....................................122-123
to statement of changes in financial position ....................122-123
to statement of income ....................122-123
to statement of retained earnings ...................122-123
Nonutility property .....................221
Nuclear fuel materials .......................202-203
Nuclear generating plant,statistics ...................402-403
Number of Electric Department Employees ....................323
Officers and officers'salaries ....................104
Operating
expenses-electric .....................320-323
expenses-electric (summary)......................323
Other
paid-in capital ..............................253
donations received from stockholders ...................253
gains on resale or cancellation of reacquired
capital stock .........................253
miscellaneous paid-in capital ............................253
reduction in par or stated value of capital stock ...................253
regulatory assets .....................232
regulatory liabilities ....................278
Overhead,construction-electric ...................217
Peaks,monthly,and output ......................401
Plant,Common utility
accumulated provision for depreciation .....................356
acquisition adjustments .....................356
allocated to utility departments ...................356
completed construction not classified ......................356
construction work in progress ......................356
expenses .....................356
held for future use .....................356
in service .......................356
leased to others ......................356
Plant data ......................217-218
336-337
401-429
FERC FORM NO.1 (ED.12-95)Index 3
INDEX (continued)
Schedule PageNo.
Plant -electric
accumulated provision for depreciation ......................219
construction work in progress ....................216
held for future use ......................214
in service .....................204-207
leased to others ..............................................213
Plant -utility and accumulated provisions for depreciation
amortization and depletion (summary)....................201
Pollution control facilities,accumulated deferred
income taxes .....................234
Power Exchanges ..............................326-327
Premium and discount on long-term debt ...................256
Premium on capital stock ....................251
Prepaid taxes ...........................262-263
Property -losses,extraordinary ....................230
Pumped storage generating plant statistics ....................408-409
Purchased power (including power exchanges)....................326-327
Reacquired capital stock ......................250
Reacquired long-term debt ....................256-257
Receivers'certificates ........................................256-257
Reconciliation of reported net income with taxable income
from Federal income taxes .....................261
Regulatory commission expenses deferred ...................233
Regulatory commission expenses for year .....................350-351
Research,development and demonstration activities ..................352-353
Retained Earnings
amortization reserve Federal .....................119appropriated.......................118-119
statement of,for the year ....................118-119unappropriated.....................118-119
Revenues -electric operating ....................300-301
Salaries and wages
directors fees .....................105
distribution of ....................354-355
officers'..............................104
Sales of electricity by rate schedules ....................304
Sales -for resale ...................310-311
Salvage -nuclear fuel .....................202-203
Schedules,this report form ....................2-4
Securities
exchange registration .......................250-251
holders and voting powers .....................106-107
Statement of Cash Flows .....................120-121
Statement of income for the year ....................114-117
Statement of retained earnings for the year ...................118-119
Steam-electric generating plant statistics .....................402-403
Stock liability for conversion ...................252
Substations .......................426
Supplies -materials and .....................227
FETIC FORM NO.1 (ED.12-90)Index 4
INDEX (continued)
Schedule Paqe No.
Taxes
accrued and prepaid .......................262-263
charged during year .........................262-263
on income,deferred and accumulated ......................234
272-277
reconciliation of net income with taxable income for ....................261
Transformers,line -electric .....................429
Transmission
lines added during year .....................424-425
lines statistics .....................422-423
of electricity for others ....................328-330
of electricity by others .....................332
Unamortized
debt discount ......................256-257
debt expense .....................256-257
premium on debt ................................256-257
Unrecovered Plant and Regulatory study Costs ...................230
FERC FORM NO.1 (ED.12-90)Index 5
ANNUAL REPORT
IDAHO SUPPLEMENT TO FERC FORM 1
MULTI-STATE ELECTRIC COMPANIES
INDEX
Page
Number Title
1 Statement of Income for the Year
2 Taxes Allocated to Idaho
3 Notes and Accounts Receivable
3 Accumulated Provision for Uncollectible Accounts
4 Receivables from Associated Companies
5 Gain or Loss on Disposition of Property
6 Professional or Consultative Services
7-10 Electric Plant in Service
11 Electric Operating Revenues
12-15 Electric Operation and Maintenance Expenses
15 Number of Electric Department Employees
STATE OF IDAHO -ALLOCATED
Idaho Power Company An Original December 31,2000
STATEMENT OF INCOME FOR THE YEAR
1.Report amounts for accounts 412 and 413,Revenue and Expenses from Utility Plant Leased to Others,in another utility
column (i,k,m,o)in a similar manner to a utility department.Spread the amount(s)over lines 01 thru 24 as appropriate.
Include these amounts in columns (c)and (d)totals.
2.Report amounts in account 414,Other Utility Operating Income,in the same manner as accounts 412 and 413 above.
3.Report data for lines 7,9,and 10 for Natural Gas companies using accounts 404.1,404.2,404.3,407.1,and 407.2.
4.Use page 122 for important notes regarding the state ment of income or any account thereof.
5.Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a
material amount may need to be made to the utility's customers or which may result in a material refund to the utility
with respect to power or gas purchases.State for each year affected the gross revenues or costs to which the contingency
relates and the tax effects together with an explanation of retain such revenues or recover amounts paid with respect
to power and gas purchases.
6.Give concise explanations concerning significant amounts of any refunds made or received during the year.
(Ref.)
Line Account Page TOTAL
No.No.Current Year Previous Year
(a)(b)(c)(d)
1 UTILITY OPERATING INCOME
2 Operating Revenues (400)................................11 $760,501,102 $596,458,052
3 Operating Expenses
4 Operation Expenses (401)................................15 471,616,823 313,036,803
5 Maintenance Expenses (402)...................................15 42,758,784 38,094,111
6 Depreciation Expense (403)........................69,520,984 67,343,763 .
7 Amort.&Depl.of Utility Plant (404-405).........................3,525,105 2,948,583 '
8 Amort.of Utility Plant Acq.Adj.(406)....,...
9 Amort.of Property Losses,Unrecovered Plant and --
Regulatory Study Costs (407).......
10 Amort.of Conversion Expenses (407)...........................
--
11 Regulatory Debits (407.3).........................-
12 (Less)Regulatory Credits (407.4).........................--
13 Taxes Other Than IncomeTaxes (408.1)..................................2 17,959,024 19,267,226
14 Income Taxes -Federal (409.1)..............................2 (9,889,742)38,636,326
15 -Other (409.1)....................................................2 (3,505,367)7,820,743
16 Provision for Deferred Income Taxes (410.1 &411.1)Net..................................2 46,942,113 (2,975,275)
18 Investment Tax Credit Adj.-Net (411.4)...............................2 (1,256,397)(1,768,261)
19 (Less)Gains from Disp.of Utility Plant (411.6).......
20 Losses from Disp.of Utility Plant (411.7).........................--
21 (Less)Gains from Disposition of Allowances (411.8).........................-
22 Losses from Disposition of Allowances (411.9).........................-
23 TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 22)....................637,671,328 482,404,019
24 Net Utility Operating Income (Enter Total of line 2 less 23)
(Carry forward to page 11,line 27).....................$122,829,774 $114,054,034
IDAHO SUPPLEMENT Page 1
STATE OF IDAHO -ALLOCATEDIdahoPowerCompanyAnOriginal December 31,2000
TAXES ALLOCATED TO IDAHO
Taxes Charged
Kind of Tax During Year
Taxes Other Than Income Taxes:
Labor Related:
FlCA.........................................$7,181,856
FUTA..........................98,966
State Unemployment............................103,733
Payroll Deduction &Loading...............................(7,504,399)
Total Labor Related..............................(119,843)
Property Taxes..................................14,951,573
Kilowatt-hour Tax.................................1,436,692
Licenses................................3,674
Regulatory Commission Fees.................................1,429,834
Irrigation PIC...............................257,094
Total Taxes Other Than Income Taxes.....................17,959,024
Federal Income Taxes................................(9,889,742)
State Income Taxes.............................(3,505,367)
Deferred Income Taxes...................................46,942,113InvestmentTaxCreditAdjustment-Net...................(1,256,397)
Total Taxes Allocated to Idaho..................................$50,249,632
IDAHO SUPPLEMENT Page 2
STATE OF IDAHO
Idaho Power Company An Original December 31,2000
NOTES AND ACCOUNTS RECEIVABLE
Summary for Balance Sheet
Show separately by footnote the total amount of notes and accounts receivable
from directors,officers,and employees included in Notes Receivable (Account
141)and Other Accounts Receivable (Account 143)
Balance Balance
Line Accounts Beginning of End of
Year Year
No.(a)(b)(c)
1 Notes Receivable (Account 141)............................................$4,449,994 $7,687,362
2 Customer Accounts Receivable (Account 142)........................................112,507,586 1,787,976,964
3 Other Accounts Receivable (Account 143).....................................3,703,241 4,885,010
4 (Disclose any capital stock subscription received)
5 Total.........................................120,660,821 1,800,549,336
6
7 Less:Accumulated Provision for Uncollectible
8 Accounts-Cr.(Account 144)...................................1,397,455 1,397,455
9
10 Total,Less Accumulated Provision for
11 Uncollectible Accounts...............................................$119,263,366 $1,799,151,881
12
13
14 Notes Receivable -Account 141:(at 12-31-00)
15 Directors,officers and employees -$4,142,154
16
17
18 Other Accounts Receivable -Account 143:(at 12-31-00)
19 Directors,officers and employees -$294,374
20
ACCUMULATED PROVISION FOR UNCOLLECTIBLE ACCOUNTS -CR.(Account 144)
1.Report below the information called for concerning this accumulated provision.
2.Explain any important adjustments of subaccounts.
3.Entries with respect to officers and empl(yees shall not incl ide items for utility services.
Mdse,
Line Item Utility Jobbing &Officers Other Total
Customers Contract and
No.(a)Work Employees
(b)(c)(d)(e)(f)
21
22 Bal.beginning of year $1,397,455 $$$$1,397,455
23 Prov.for uncollectibles
24 for year.......
25 Accounts written off.......
26 Coll.of accounts
27 written off.......
28 Adjustments (explain)........
29
30
31
32 Balance end of year...................................$1,397,455 $1,397,455
33
IDAHO SUPPLEMENT Page 3
STATE OF IDAHOIdahoPowerCompanyAnOriginal December 31,2000
RECEIVABLES FROM ASSOCIATED COMPANIES (Accounts 145,146)
1.Report particulars of notes and accounts receivable from associated companies at end of year.
2.Provide separate headings and totals for accounts 145,Notes Receivable from Associated Companies,and 146,
Accounts Receivable from Associated Companies,in addition to a total for the combined accounts.
3.For notes receivable list each note separately and state purpose for which received.Show also in column
(a)date of note,date of maturity and interest rate.
4.If any note was received in satisfaction of an open account,state the period covered by such open account.
5.Include in column (f)interest recorded as income during the year,including interest on accounts and notes
held at any time during the year.
6.Give particulars of any notes pledged or discounted,also of any collateral held as guarantee of payment
of any note or account.
Balance
Line Particulars Beginning Totals for Year Balance Interest
of Year Debits Credits End of Year For YearNo.(a)(b)(c)(d)(e)(f)
1 Account 145:
2
3 None
4
5
6
7
8
9
10
11
12 Account 146:
13
14
15
16
17 IDACORP,Financial Services........$11,685 $455,641 $439,940 $27,386
18
19 Ida-West Energy
20 Company..........................634 17,876 8,799 9,711
21
22
23 Applied Power Corp...................-12,075 11,060 1,015
24
25 Rocky Mountain Communication -78,120 1,365 $76,755
26
27 IDACORP,Inc............................(27,121)53,168,084 53,311,018 (170,055)
28
29 IDACORP Energy Solutions..........221,048 624,118 479,175 365,991
30
31 Total Account 146..........................$206,246 $53,731,796 $53,772,182 $310,803
32
IDAHO SUPPLEMENT Page 4
STATE OF IDAHO
Idaho Power Company An Original December 31,2000
STATE OF IDAHO -TOTAL SYSTEM DATA
GAIN OR LOSS ON DISPOSITION OF PROPERTY (Account 421.1 and 421.2)
1.Give a brief description of property creating the gain or loss.Include name of party acquiring the property (when
acquired by another utility or associated company)and the date transaction was completed.Identify property
by type,Leased,Held for Future Use,or Nonutility.
2.Individual gains or losses relating to property with an original cost of less than $50,000 may be grouped,with the
number of such transactions disclosed in column (a).
3.Give the date of Commission approval of journal entries in column (b),when approval is required.Where approval
is required but has not been received,give explanation following the item in column (a).(See account 102,Utility
Plant Purchased or Sold.)
Original Cost Date Journal
Line Description of Property of Related Entry Approved Acct 421.1 Acct 421.2
Property (When Required)
No.(a)(b)(c)(d)(e)
1 Gain on disposition of
2 property:
3
4 Boise Substation Building Sale $215,048 $110,504
5
6 Nampa Office Sale 12,176 177,399
7
8 IPCO to IdaCorp transfer 302,880 (302,880)
9
10
11
12 Miscellaneous items (9)39,303 55,533
13
14 Total gain...........................................$569,407 $40,556
15
16 Loss on disposition of
17 property:(2 item)$69,498 $2,200
18
19
20
21
22
23
24
25
26
27
28
29
30
31 Total loss........................................$69,498 $2,200
IDAHO SUPPLEMENT Page 5
STATE OF IDAHOIdahoPowerCompanyAnOriginal December 31,2000
STATE OF IDAHO -TOTAL SYSTEM DATA
PROFESSIONAL OR CONSULTATIVE SERVICES -ITEMS $10,000 AND OVER
Line PAYEE SERVICE TYPE AmountNo.(a)(b)(c)
1 ANALYSIS GROUP ECONOMICS Management Services $30,990
2 ASC GROUP Wetland Mitigation 299,144
3 BEACON HILL PARTNERS Management Services 21,055
4 BEST CONSULTING Programming Services 156,669
5 BIDART &ROSS INC Management Services 32,000
6 BLUE HERON CONSULTING,INC Data Processing Services 818,371
7 BRENNEMAN,JOHN Govermental Relations Counsel 50,521
8 BURKE CSA Customer Satisfaction Services 315,300
9 BUSINESS LEGAL CONSULTING Legal Services 17,21610CH2MHILLEngineeringServices125,479
11 CHURCH,JOHN S Economic analysis services 72,00012CORNERSTONESYSTEMSINCProgrammingServices1,000,00013CRI/THE RESOURCE GROUP,INC.Programming Services 111,609
14 CRISTOPHER F HOPPER Legal Services 54,91715CROW,BRETT D Economic analysis services 10,66016DELOlTEANDTOUCHELLPExternalAuditors492,303
17 'DENTON,MARY K Legal Services 12,53418DHlINCEnvironmentalServices18,200
19 DORSEY &WHITNEY LLP Management Services 106,90720DUKEENGINEERINGSERVICES-Engineering Services 29,557
21 ENERX DEVELOPMENT INC Management Services 76,55522EVANSKEANELegalServices224,968
23 EXACTA CORPORATION Data Processing Services 248,881
24 HALL FARLEY OBERRECHT &B Legal Services 67,359
25 HAWLEY TROXELL ENNIS &HAWLEY Legal Services 11,210
26 HDR ENGINEERING,INC Engineering Services 27,964
27 HOLLAND CONSULTING GROUP Management Services 10,494
28 IOWA INSTITUTE OF HYDRAULICS Management Services 207,000
29 JONES CHARTERED Legal Services 25,505
30 KILPATRICK,JOHNSON &ADLER Management Services 33,982
31 LE BOEUF LAMB GREENE Management Services 461,390
32 LEIGHTON &SHERLINE Management Services 14,464
33 LUYET CONSULTING Management Services 46,954
34 MCCLURE,GERARD &NEUENSCHWAND Management Services 91,115
35 MILLER BATEMAN LLP Legal Services 152,977
36 MOBLEY ENGINEERING Engineering Services 66,357
37 MOODY'S RISK MANAGEMENT SERVIC Management Services 11,898
38 MYCOFF &ASSOCIATES,INC Management Services 11,263
39 NAVIGANT CONSULTING,INC Customer survey 65,00040NIELSENGROUPINC,THE Data Processing Services 363,821
41
42
Page 3
IDAHO SUPPLEMENT
STATE OF IDAHO
Idaho Power Company An Original December 31,2000
STATE OF IDAHO -TOTAL SYSTEM DATA
PROFESSIONAL OR CONSULTATIVE SERVICES -ITEMS $10,000 AND OVER
Line PAYEE SERVICE TYPE
No.(a)(b)
1 NOLAND,M ROY Engineering Services $15,750
2 NORTHWEST ARCHAEOLOGlCAL Archaeological Serviœs 35,514
3 NORTHWEST STRATEGIES Management Services 120,427
4 OAKWOOD CONSULTING Environmental Services 21,006
5 OCM Management Services 35,530
6 PANTER,GREGORY W Legislative Advisor 75,195
7 POWER ENGINEERS Engineering Services 36,174
8 PRICE WATERHOURS COOPERS Management Services 62,682
9 RW BECK Management Services 29,110
10 RALSTON &ASSOCIATES Engineering Services 45,299
11 RAPlDIGM INC Data Processing Services 55,273
12 RESERVOIR ENVIRONMENTAL MANAGE Environmental Services 50,471
13 RIDDELL,WILLIAM Management Services 13,220
14 RISK ADVISORY Management Services 102,871
15 ROBERT J RIETH Management Services 25,493
16 ROSHOLT,ROBERTSON &TUCKER Legal Services 440,130
17 SALLADAY,G LANCE Legal Services 31,953
18 STEPTOE &JOHNSON LLP Legal Services 392,310
19 SVERDRUP CIVIL,INC Environmental Services 83,835
20 TAYLOR ENGINEERING,lNC Engineering Services 23,276
21 TERRY PAGE CONSULTING Management Services 23,335
22 THE UPLINE GROUP,INC CIS project consulting 58,204
23 THOMPSON FINANCIAL INVESTOR Management Services 42,500
24 US GEOLOGICAL SURVEY Environmental Services 55,048
25 VAN NESS FELDMAN Management Services 203,043
26 WEBER PH.D,LARRY J Environmental Services 11,555
27 WEFA Management Services 21,000
28 YTURRI,ROSE,BURNHAM,BENTZ Legal Services 44,389
29 ZIMMER &ASSOCIATES Relicensing Services 108,405
30
31
32
33
34
35
36
37
38
39
40
41
42
Page 6-A
IDAHO SUPPLEMENT
STATE OF IDAHO
Idaho Power Company An Original December 31,2000
PROFESSIONAL OR CONSULTATIVE SERVICES
ITEMS $5.000 OR MORE BUT LESS THAN $10.000
PREDOMINANT
PAYEE NATURE OF SERVICE AMOUNT
ALTMAN WEIL INC MANAGEMENT SERVICES $5,945
BECKLUND &ASSOCIATES MANAGEMENT SERVICES 7,294
BLACK &VEATCH ENGINEERING SERVICES 9,490
COALE,WILLIAM MANAGEMENT SERVICES 8,000
FINANCIAL ENGINEERING ASSOCIATES MANAGEMENT SERVICES 5,250
INVESTORTOOLS,INC MANAGEMENT SERVICES 9,000
LANE POWELL SPEARS LUBERSKY LEGAL SERVICES 9,806
STOELL RIVES,LLP ENVIRONMENTAL SERVICES 7,595
IDAHO SUPPLEMENT Page 6-B
STATE OF IDAHO-ALLOCATED
Idaho Power Company An Original December 31,2000
ELECTRICPLANT IN SERVICE(Accounts 101,102,103 and 106)
1.Report below the original cost of electric plant in service according to the prescribed accounts.
2.In addition to Account 101,Electric Plant in Service (Classified),this page and the next include Account 102,Electric Plant
Purchased or Sold;Account 103,Experimental Electric Plant Unclassified;and Account 106,Completed Construction
Not Classified -Electric.
3.Include in column (c)or (d),as appropriate,corrections of additions and retirements for the current or preceding year.
4.Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
5.Classify Account 106 according to prescribed accounts,on an estimated basis if necessary,and include the entries in
column (c).Also to be included in column (c)are entries for reversals of tentative distributions of prior year reported in
column (b).Likewise,if one respondent has a significant amount of plant retirements the end of the year,include in
column (d)a tentative distribution of such retirements,on an estimated basis,with appropriate contra entry to the account
for accumulated depreciation provision.Include also in column (d)reversals of tentative distributions of prior year of un-
classified retirements.Attach supplemental statement showing the account distributions of these tentative classifications in
columns (c)and (d),including the reversals of the prior years tentative account distributions of these amounts.Careful ob-
servance of the above instructions and the te×ts of Accounts 101 and 106 will avoid serious omissions of the reported amount
of respondent's plant actually in service at end of year.
Line Balance at
Account Beginning of year Additions
No.(a)(b)(c)
1 1.INTANGlBLEPLANT
2 (301)Organization..........................................$6,023
3 (302)Franchises and Consents.......................2,713,284
4 (303)Miscellaneous Intangible Plant........................22,318,782
5 TOTAL Intangible Plant (Enter Total of lines 2,3,and 4)......................25,038,088
6 2.PRODUCTIONPLANT
7 A.Steam Production Plant
8 (310)Land and Land Rights.......
9 (311)Structures and Improvements....
10 (312)Boiler Plant Equipment.....
11 (313)Engines and Engine Driven Generators.......
12 (314)Turbogenerator Units......
13 (315)Accessory Electric Equipment......
14 (316)Misc.Power Plant Equipment......
15 TOTAL Steam Production Plant (Enter Total of lines 8 thru 14)....................670,592,080
16 B.Nuclear Production Plant
17 (320)Land and Land Rights......
18 (321)Structures and Improvements.......
19 (322)Reactor Plant Equipment.......
20 (323)Turbogenerator Units......
21 (324)Accessory Electric Equipment.......
22 (325)Misc.Power Plant Equipment.......
23 TOTAL Nuclear Production Plant (Enter Total of lines 17 thru 22).......
24 C.Hydraulic Production Plant
25 (330)Land and Land Rights.......
26 (331)Structures and Improvements......
27 (332)Reservoirs,Dams,and Waterways......
28 (333)Water Wheels,Turbines,and Generators.......
29 (334)Accessory Electric Equipment......
30 (335)Misc.Power Plant Equipment.......
31 (336)Roads,Railroads,and Bridges......
32 TOTAL Hydraulic Production Plant (Enter Total of lines 25 thru 31).......................554,978,161
33 D.Other Production Plant
34 (340)Land and Land Rights.......
35 (341)Structures and Improvements......
36 (342)Fuel Holders,Products and Accessories......
37 (343)Prime Movers.....
38 (344)Generators......
39 (345)Accessory Electric Equipment.....
Page 7
IDAHOSUPPLEMENT
STATE OF IDAHO-ALLOCATEDIdahoPowerCompanyAnOriginal December 31,2000
ELECTRICPLANT IN SERVICE(Accounts 101,102,103 and 106)(Continued)
6.Show in column (f)reclassifications or transfers within utility plant accounts.Include also in column
(f)the additions or reductions of primary account classifications arising from distribution of amountsinitiallyrecordedinAccount102.In showing the clearance of Account 102,include in column (e)theamountswithrespecttoaccumulatedprovisionfordepreciation,acquisition adjustments,etc.,and show
in column (f)only the offset to the debits or credits distributed in column (f)to primary account classifications.
7.For Account 399,state the nature and use of plant included in this account and if substantial in amountsubmitasupplementarystatementshowingsubaccountclassificationofsuchplantconformingtotherequirementsofthesepages.
8.For each amount comprising the reported balance and changes in Account 102,state the property purchasedorsold,name of vendor or purchaser,and date of transaction.If proposed journal entries have been filedwiththeCommissionasrequiredbytheUniformSystemofAccounts,give also date of such filing.
Balance at LineRetirementsAdjustmentsTransfersEndofYear
(d)(e)(f)(g)No.
1
$6,069 (301)2
8,024,733 (302)3
39,435,206 (303)4
47,466,007 5
6
7
(310)8
(311)9
(312)10
(313)11
(314)12
(315)13
(316)14
685,232,731 15
16
(320)17
(321)18
(322)19
(323)20
(324)21
(325)22
23
24
(330)25
(331)26
(332)27
(333)28
(334)29
(335)30
(336)31
568,513,882 32
33
(340)34
(341)35Informationisavailableonlyonanendofyearbasis.(342)36
(343)37
(344)38
(345)39
Page 8
IDAHO SUPPLEMENT
STATE OF IDAHO-ALLOCATED
Idaho Power Company An Original December 31,2000
ELECTRICPLANT IN SERVICE(Accounts 101,102,103 and 106)(Continued)
Line Balance at
Account Beginning of year Additions
No.(a)(b)(c)
40 (346)Misc.Power Plant Equipment.......
41 TOTAL Other Production Plant (Enter Total of lines 34 thru 40)..................................$575,016
42 TOTAL Production Plant (Enter Total of lines 15,23,32,and 41)......................1,226,145,257
43 3.TRANSMISSIONPLANT
44 (350)Land and Land Rights.....................8,664,912
45 (352)Structures and improvements.....................18,117,052
46 (353)Station Equipment.......................136,900,714
47 (354)Towers and Fixtures.......................43,116,937
48 (355)Poles and Fixtures.........................54,839,296
49 (356)Overhead Conductors and Devices......................70,260,062
50 (357)Underground Conduit..........................-
51 (358)Underground Conductors and Devices.....................-
52 (359)Roads and Trails.......................................................255,945
53 TOTAL Transmission Plant (Enter Total of lines 44 thru 52).......................332,154,918
54 4.DISTRIBUTIONPLANT
55 (360)Land and Land Rights......................1,678,437
56 (361)Structures and Improvements..........,..........10,580,476
57 (362)Station Equipment.......................86,135,929
58 (363)Storage Battery Equipment........
59 (364)Poles,Towers,and Fixtures.......................141,915,278
60 (365)Overhead Conductors and Devices.......................77,459,939
61 (366)Underground Conduit...........................22,646.109
62 (367)Underground Conductors and Devices......................104,428,588
63 (368)Line Transformers.....................210,411,110
64 (369)Services........................34,028,950
65 (370)Meters.............................................33,998,378
66 (371)Installations on Customer Premises....................1,847,648
67 (372)Leased Property on Customer Premises.......
68 (373)Street Lighting and Signal Systems...........................3,452,746
69 TOTAL Distribution Plant (Enter Total of lines 55 thru 68)....................728,583,586
70 5.GENERALPLANT
71 (389)Land and Land Rights.......................7,909,974
72 (390)Structures and improvements.......................47,346,969
73 (391)Office Furniture and Equipment......................30,040,324
74 (392)Transportation Equipment.....................28,096,565
75 (393)Stores Equipment............................773,382
76 (394)Tools,Shop and Garage Equipment....................2,567,500
77 (395)Laboratory Equipment......................6,386,863
78 (396)Power Operated Equipment..........................6,726,398
79 (397)Communication Equipment.......................13,309,713
80 (398)Miscellaneous Equipment........................1,607,735
81 SUBTOTAL (Enter Total of lines 71 thru 80).....................144,765,423
82 (399)Other Tangible Property......
83 TOTAL General Plant (Enter Total of lines 81 and 82)......................144,765,423
84 TOTAL (Accounts 101 and 106)....................2,456,687,273
85 (102)Electric Plant Purchased ....
86 (Less)(102)Electric Plant Sold........
87 (103)Experimental Plant Unciassified......
88 TOTAL Electric Plant in Service.....................................$2,456,687,273
Page 9
IDAHOSUPPLEMENT
STATE OF IDAHO -ALLOCATEDIdahoPowerCompanyAnOriginal December 31,2000
ELECTRICPLANT IN SERVICE(Accounts 101,102,103 and 106)(Continued)
Balance at LineRetirementsAdjustmentsTransfersEndofYear(d)(e)(f)(g)No.
(346)40
$583,097 41
1,254,329,710 42
43
9,823,223 (350)44
18,651,230 (352)45
138,870,665 (353)46
44,061,906 (354)47
55,268,792 (355)48
72,222,159 (356)49
-(357)50
-(358)51
256,618 (359)52
339,154,594 53
54
1,817,650 (360)55
10,969,078 (361)56
89,860,545 (362)57
-(363)58
143,170,036 (364)59
77,322,960 (365)60
24,761,159 (366)61
108,329,705 (367)62
218,962,098 (368)63
36,208,634 (369)64
35,188,995 (370)65
1,781,313 (371)66
-(372)67
3,410,385 (373)68
751,782,558 69
70
7,963,580 (389)71
47,978,802 (390)72
33,717,448 (391)73
30,605,243 (392)74
767,030 (393)75
2,614,958 (394)76
6,505,363 (395)77
5,216,142 (396)78
13,523,557 (397)79
1,629,701 (398)80
150,521,824 81
(399)82
150,521,824 83
2,543,254,693 84
(102)85
86
(103)87
$2,543,254,693 88
Page 10
IDAHOSUPPLEMENT
STATE OF IDAHO -ALLOCATED
Idaho Power Company An Original December 31,2000
ELECTRIC OPERATING REVENUES (Account 400)
1.Report below operating revenues for each prescribed account,and manufactured gas revenues in total.
2.Report number of customers,columns (f)and (g),on the basis of meters,in addition to the number of flat rate
accounts;except that where separate meter readings are added for billing purposes,one customer should be counted
for each group of meters added.The average number of customers means the average of twelve figures at the close
of each month.
3.If previous year (columns (c),(e)and (g),are not derived from previously reported figures,explain any
inconsistencies in a footnote.
OPERATING REVENUES
Amount for Amount for
No.Current Year Previous Year
(a)(b)(c)
1 Sales of Electricity
2 (440)Residential Sales..............................................$215,560,768 $203,972,260
3 (442)Commercial and Industrial Sales
4 Small (or Commercial)(See Instr.4)(1).......................194,748,043 173,529,219
5 Large (or industrial)(See Instr.4)(2).........................125,356,736 109,990,432
6 Non-Juristictional Sales -Embarcadero -(allocated)....................-(2,917)
7 (444)Public Street and Highway Lighting........................2,069,765 2,076,730
8 (445)Other Sales to Public Authorities.........
9 (446)Sales to Railroads and Railways........
10 (448)Interdepartmental Sales........
11 TOTAL Sales to Ultimate Consumers........................537,735,312 *489,565,724
12 (447)Sales for Resale -Opportunity....Non-Firm Only....................191,842,607 93,669,403
13 TOTAL Sales of Electricity........................729,577,919 583,235,127
14 (Less)(449.1)Provision for Rate Refunds........................(4,474,516)9,277,380
15 TOTAL Revenue Net of Provision for Refunds........................734,052,435 573,957,747
16 Other Operating Revenues
17 (450)Forfeited Discounts........
18 (451)Miscellaneous Service Revenues.........................2,808,266 2,941,607
19 (453)Sales of Water and Water Power........
20 (454)Rent from Electric Property........................17,102,596 11,419,257
21 (455)Interdepartmental Rents........
22 (456)Other Electric Revenues......................6,537,805 8,139,440
23
24
25
26 TOTAL Other Operating Revenues.........................26,448,666 22,500,304
27 TOTAL Electric Operating Revenues..........................................$760,501,102 $596,458,051
(1)Commercial and Industrial sales -Small -under 1,000 KW and includes all irrigation customers.
(2)Commercial and Industrial sales -Large -1,000 KW and over.
Page 11
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
Idaho Power Company An Original December 31,2000
ELECTRIC OPERATING REVENUES (Account 400)(Continued)
4.Commercial and Industrial Sales,Account 442,may be classified according to the basis of classification
(Small or Commercial,and Large or Industrial)regularly used by the respondent if such basis of classification
is not generally greater than 1000 Kw of demand.(See Account 442 of the Uniform System of Accounts.Explain
5.See page 108,Important Changes During Year,for important new territory added and important rate increases or
decreases.
6.For lines 2,4,5,and 6,see page 304 for amounts relating to unbilled revenue by accounts.
7.Include unmetered sales.Provide details of such sales in a footnote.
KILOWATT HOURS SOLD AVERAGE NUMBER OF C JSTOMERS PER MONTH
Amount for Amount for Amount for Numberfor Line
Current Year Previous Year Current Year Previous Year No.
(d)(e)(f)(g)
1
4,189,182,972 3,997,632,389 309,499 300,072 2
3
5,144,299,719 4,653,892,808 60,321 59,677 4
4,533,600,770 4,398,085,668 104 105 5
6
28,394,087 28,230,923 177 167 7
8
9
10
13,895,477,548 **13,077,841,788 **370,101 360,021 11
3,522,956,707 4,814,422,447 N/A N/A 12
17,418,434,255 17,892,264,235 370,101 360,021 13
14
*Includes $12,059,185 unbilled revenues.
**Includes 227,771,344 KWH relating to unbilled revenues.
lines 6,12 &17 through 27 are on an "allocated"basis.
Page 11a
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATED
Idaho Power Company An Original December 31,2000
ELECTRICOPERATIONAND MAINTENANCEEXPENSES
If the amount for previous year is not derived from previously reported figures,explain in footnotes.
Line Amount for Amount for
No.Account Current Year Previous Year
(a)(b)(c)
1 1.POWERPRODUCTIONEXPENSES
2 A.Steam Power Generation
3 Operation
4 (500)Operation Supervision and Engineering.....................................5 1,765,469 $2,052,122
5 (501)Fuel......................................................................................................................85,577,259 78,686,280
6 (502)Steam Expenses.............................................................................................................5,369,162 4,169,059
7 (503)Steam from Other Sources.................................................................................................O
8 (Less)(504)Steam Transferred-Cr.............................................................................................O -
9 (505)Electric Expenses..............................................................................................................1,245,039 1,190,748
10 (506)Miscellaneous Steam Power Expenses..........................10,316,507 11,326,194
11 (507)Rents.................................................543,003 537,375
12 (509)Allowances.....................0 -
13 TOTAL Operation (Enter Total of lines 4 thru 12)........................104,816,438 97,961,778
14 Maintenance
15 (510)Maintenance Supervision and Engineering.........................................................................1,513,643 1,171,040
16 (511)Maintenanceof Structures..................................................................................................274,609 136,725
17 (512)Maintenance of Boiler Plant................................................................................................6,185,229 6,785,865
18 (513)Maintenanceof Electric Plant..............................................................................................1,660,394 2,446,815
19 (514)Maintenanceof Miscellaneous Steam Plant........................................................................2,543,678 1,230,341
20 TOTAL Maintenance (Enter Total of Lines 15 thru 19)......................12,177,553 11,770,787
21 TOTAL Power Production Expenses-Steam Power (Enter Total of lines 13 and 20)..............116,993,991 109,732,565
22 B.Nuclear Power Generation
23 Operation
24 (517)Operation Supervision and Engineering.......
25 (518)Fuel......
26 (519)Coolants and Water......
27 (520)Steam Expenses......
28 (521)Steam from Other Sources......
29 (Less)(522)Steam Transferred-Cr.......
30 (523)Electnc Expenses....
31 (524)Miscellaneous Nuclear Power Expenses....
32 (525)Rents.
33 TOTAL Operation (Enter Total of lines 24 thru 32)......
34 Maintenance
35 (528)Maintenance Supervision and Engineering......
36 (529)Maintenance of Structures.......
37 (530)Maintenance of Reactor Plant Equipment.......
38 (531)Maintenance of Electric Plant........
39 (532)Maintenance of Miscellaneous Nuclear Plant.......
40 TOTAL Maintenance (Enter Total of lines 35 thru 39).......
41 TOTAL Power Production Expenses-Nuclear Power (Enter Total of lines 33 and 40)......
42 C.Hydraulic Power Generation
43 Operation
44 (535)Operation Supervision and Engineering..............................................................................3,015,185 2,820,592
45 (536)Water for Power.................................................................................................................3,542,880 4,404,139
46 (537)Hydraulic Expenses............................................................................................................3,936,036 3,605,179
47 (538)Electric Expenses..............................................................................................................924,778 919,253
48 (539)Miscellaneous Hydraulic Power Generation Expenses............................................1,546,359 1,602,700
49 (540)Rents......................................................................................................323,683 316,340
50 TOTAL Operation (Enter Total of lines 44 thru 49)......................13,288,922 13,668,204
Page 12
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATEDIdahoPowerCompanyAnOriginal December 31,2000
ELECTRICOPERATIONAND MAINTENANCEEXPENSES
If the amount for previous year is not derived from previously reported figures,explain in footnotes.
Line 'Amount for i Amount forNo.Account Current Year Previous Year(a)(b)(c)
51 C.Hydraulic Power Generation (Continued)
52 Maintenance
53 (541)Maintenance Supervision and Engineering.........................................................................5 872,217.78 5 698,21654(542)Maintenance of Structures..................................................................................................1,057,116 1,007,13755(543)Maintenance of Reservoirs,Dams,and Waterways............................................................697,799 671,44056(544)Maintenance of Electric Plant.............................................................................................2,366,810 2,700,21157(545)Maintenance of Miscellaneous Hydraulic Plant..................................................................2,027,643 1,934,703
58 TOTAL Maintenance (Enter Total of lines 53 thru 57)........................7,021,586 7,011,707
59 TOTAL Power Production Expenses-Hydraulic Power (Enter Total of lines 50 and 58)...........20,310,508 20,679,911
61 Operation
62 (546)Operation Supervision and Engineering.......................0 4,96163(547)Fuel....................................................................................................................................255,010 8,03664(548)Generation Expenses.........................................................................................................5,296 4,27265(549)Miscellaneous Other Power Generation Expenses.............................................................2,794 89866(550)Rents................................................................O -
67 TOTAL Operation (Enter Total of lines 62 thru 66)......................263,099 18,167
68 Maintenance
69 (551)MaintenanceSupervisionand Engineering.........................................................................O 88670(552)Maintenanceof Structures.................................................................................................1,307 12971(553)Maintenance of Generating and Electric Plant............................86,312 17,90772(554)Maintenance of Miscellaneous Other Power Generation Plant.........................0 101
I73TOTALMaintenance(Enter Total of lines 69 thru 72).......................87,620 19,023
74 TOTAL Power Production Expenses-Other Power (Enter Total of lines 67 and 73).................350,719 37,190
75 E.Other Power Supply Expenses
76 (555)Purchased Power................................................................................................363,211,063 96,618,92377(556)System Control and Load Dispatching................................................................................1,204,068 1,206,34578(557)Other Expenses..................................................................................................................(111,277,230)172,507
79 TOTAL Other Power Supply Expenses (Enter Total of lines 76 thru 78).........................253,137,901 97,997,775
80 TOTAL Power Production Expenses (Enter Total of lines 21,41,59,74,and 79)...................390,793,119 228,447,441
81 2.TRANSMISSIONEXPENSES
82 Operation
83 (560)Operation Supervision and Engineering..............................................................................1,525,075 1,828,60584(561)Load Dispatching................................................................................................................1,765,936 1,646,79285(562)Station Expenses................................................................................................................1,099,830 123,50686(563)Overhead Line Expenses....................................................................................................474,189 246,01887(564)Underground Line Expenses...............................................................................................195,624 2,506,68688(565)Transmission of Electricity by Others..................................................................159,031 682,69989(566)Miscellaneous Transmission Expenses.............................................1,199,223 1,036,82490(567)Rents............................................................O
91 TOTAL Operation (Enter Total of lines 83 thru 90)........................6,418,907 8,071,130
92 Maintenance
93 (568)Maintenance Supervision and Engineering.........................................................................402,137 274,70494(569)Maintenanceof Structures..................................................................................................0 2795(570)Maintenanceof Station Equipment.....................................................................................2,260,005 1,737,88496(571)MaintenanceofOverhead Lines.........................................................................................1,630,072 1,531,15397(572)Maintenanceof Underground Lines....................................................................................0 6398(573)Maintenance of Miscellaneous Transmission Plant.............................................................0 -
99 TOTAL Maintenance (Enter Total of lines 93 thru 98)........................4,292,214 3,543,831
100 TOTAL Transmission Expenses (Enter Total of lines 91 and 99).........................10,711,122 11,614,961
102 Operation
103 (580)Operation Supervision and Engineering.....................3,532,700 4,341,217
Page 13
IDAHOSUPPLEMENT
STATE OF IDAHO-ALLOCATED
Idaho Power Company An Original December 31,2000
I
ELECTRICOPERATIONAND MAINTENANCEEXPENSES
If the amount for previous year is not derived from previously reported figures,explain in footnotes.
Line Amount for Amount for
No.Account Current Year Previous Year
(a)(b)(c)
104 3.DISTRIBUTIONEXPENSES(Continued)
105 (581)Load Dispatching...........................................................................................................5 2,408,942 5 2,232,901
106 (582)Station Expenses...............................................................................................................1,488,410 2,502,619
107 (583)Overhead Line Expenses...................................................................................................3,372,377 2,671,388
108 (584)Underground Line Expenses.............................................................................................2,598,386 1,966,180
109 (585)Street Lighting and Signal Systern Expenses......................................................................619,418 215,494
110 (586)Meter Expenses..................................................................................................................3,495,726 2,729,835
111 (587)Custorner Installations Expenses........................................................................................456,584 693,474
112 (588)Miscellaneous Distribution Expenses..................................................................................3,992,115 6,648,086
113 (589)Rents.................................................................................................................................124,133 130,797
114 TOTAL Operation (Enter Total of lines 103 thru 113)......................22,088,791 24,131,993
115 Maintenance
116 (590)Maintenance Supervision and Engineering........................................................................86,972 126,736
117 (591)Maintenance of Structures.................................................................................................7,874 9,168
118 (592)Maintenance of Station Equipment.....................................................................................2,870,684 1,607,457
119 (593)Maintenance of Overhead Lines.........................................................................................9,220,991 6,460,574
120 (594)Maintenance of Underground Lines....................................................................................1,480,921 1,261,412
121 (595)Maintenance of Line Transformers...................................................................................1,975,650 2,409,520
122 (596)Maintenance of Street Lighting and Signal Systems...........................................................70,216 285,035
123 (597)Maintenance of Meters..........................,...........................................................................1,659,757 1,759,003
124 (598)Maintenance of Miscellaneous Distribution Plant................................................................254,260 98,849
125 TOTAL Maintenance (Enter Total of lines 116 thru 124)........................17,627,326 14,017,753
126 TOTAL Distribution Expenses (Enter Total of lines 114 and 125).......................39,716,117 38,149,746
127 4.CUSTOMERACCOUNTSEXPENSES
128 Operation
129 (901)Supervision.........................................................................................................................441,328 140,963
130 (902)Meter Reading Expenses....................................................................................................4,408,686 4,005,469
131 (903)Customer Records and Collection Expenses......................6,241,068 6,712,058
132 (904)Uncollectible Accounts.......................................................................................................1,520,460 1,423,271
133 (905)Miscellaneous Customer Accounts Expenses.....................................................................6,458 133,399
134 TOTAL Customer Accounts Expenses (Enter Total of lines 129 thru 133)......................12,618,000 12,415,160
135 5.CUSTOMERSERVICEAND INFORMATIONALEXPENSES
136 Operation
137 (907)Supervision............................................................................................................82,433 32,087
138 (908)Customer Assistance Expenses..........................................................................................7,226,930 5,842,954
139 (909)Informational and Instructional Expenses...........................................................................133,378 79,728
140 (910)Miscellaneous Customer Service and Informational Expenses............................................482,056 642,298
141 TOTAL Cust.Service and Informational Expenses (Enter Total of lines 137 thru 140)..............7,924,796 6,597,068
142 6.SALES EXPENSES
143 Operation
144 (911)Supervision.......................................................................................................................0 -
145 (912)Demonstrating and Selling Expenses..................................................................................0 -
146 (913)Advertising E×penses.......................................................................................................O -
147 (916)Miscellaneous Sales Expenses....................O -
148 TOTAL Sales Expenses (Enter Total of lines 144 thru 147).......................O -
149 7.ADMINISTRATIVEAND GENERALEXPENSES
150 Operation
151 (920)Administrative and General Salaries............................................................................31,753,668 25,488,079
152 (921)Office Supplies and Expenses............................................................................................16,568,589 13,979,502
153 (Less)(922)Administrative E×penses Transferred-Credit...........................................................(18,838,989)(16,758,445)
Page 14
IDAHO SUPPLEMENT
STATE OF IDAHO -ALLOCATEDIdahoPowerCompanyAnOriginal December 31,2000
ELECTRICOPERATIONAND MAINTENANCEEXPENSES
If the amount for previous year is not derived from previously reported figures,explain in footnotes.
Line Amount for Amount forNo.Account Current Year Previous Year(a)(b)(c)
154 7.ADMINISTRATIVEAND GENERALEXPENSES(Continued)155 (923)Outside Services Employed...................................................................5 4,029,619 5 5,115,193156(924)Property Insurance..........................................................1,539,333 1,350,063157(925)Injuries and Damages......................................................3,167,369 3,779,084158(926)Employee Pensions and Benefits.......................................7,080,334 14,041,343159(927)Franchise Requirements.........................................2,389 1,595160(928)Regulatory Cornmission Expenses...................................................................................3,467,411 2,656,543161(929)Duplicate Charges-Cr...................................................................................................0162(930.1)General Advertising Expenses.........................................................................................590,237 594,178163(930.2)Miscellaneous General Expenses....................................................................................1,666,124 1,893,190164(931)Rents...............................................................................................................................33,883 35,203
165 TOTAL Operation (Enter Total of lines 151 thru 164)......................51,059,967 52,175,528
166 Maintenance
167 (935)Maintenance of General Plant.......................1,552,486 1,731,009
168 TOTAL Administrative and General Expenses (Enter Total of lines 165thru167).................................................................................52,612,453 53,906,538
169 TOTAL Electric Operation and Maintenance Expenses (Enter Total oflines80,100,126,134,141,148,and 168)...................................................5 514,375,607 5 351,130,914
IDAHO ONLY
NUMBEROF ELECTRICDEPARTMENTEMPLOYEES
1.The data on number of employees should be reported for the payroll period ending nearest to October 31,or any payroll period ending 60 days before or after October 31.
2.If the respondent's payroll for the reporting period includes any special construction personnel,includesuchemployeesonline3,and show the number of such special construction employees in a footnote.
3.The number of employees assignable to the electric department from joint functions of combination utilities
may be determined by estimate,on the basis of employee equivalents.Show the estimated number of equiv-alent employees attributed to the electric department from joint functions.
1 Payroll Period Ended (Date).....................12/29/00
2 Total Regular Full-TimeEmployees.....................1,635
3 Total Part-Time and Temporary Employees.........................30
4 Total Employees......................1,665
Page 15
IDAHOSUPPLEMENT